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Amended Tariff, Docket No. ER16-2199 2021-01-012021-12-31 C008999 Baxter Wilson Com 314 2021-01-012021-12-31 C008999 ferc:TwoYearsMemberferc:NitrogenOxideMember 2021-01-012021-12-31 C008999 ScheduleElectricPropertyLeasedToOthersAbstract 2021-01-012021-12-31 C008999 See footnote for schedule details, 2021-01-012021-12-31 C008999 Yandell Sub Upgrades 2021-01-012021-12-31 C008999 ferc:SalesAndUseTaxMember 2021-12-31 C008999 Non Income Tax, Miscellaneous Other Tax, , 2021-12-31 C008999 Crenshaw: Add Circuit Switcher 2021-01-012021-12-31 C008999 2020 Planning SH20-005V Getwell - Eferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 JONESTOWN, Distribution, Unattended 2021-12-31 C008999 ELLIOTT, Distribution, Unattended 2021-12-31 C008999 TF-23 Traffic Control Signals 2021-01-012021-12-31 C008999 Advanced DMS 2021-01-012021-12-31 C008999 FP# F1PPU27609-Brookhaven-West McCoferc:ElectricUtilityMember 2021-12-31 C008999 Contra UA 392_RES 2021-01-012021-12-31 C008999 ferc:CurrentYearMemberferc:NitrogenOxideMember 2021-12-31 C008999 ferc:Quarter3Member Entergy Mississippi, LLC 2021-01-012021-12-31 C008999 E. Vicksburg-E. Vicksburg 115kV CAPferc:ElectricUtilityMember 2021-12-31 C008999 HOY ROAD, Distribution, Unattended 2021-01-012021-12-31 C008999 , , , 2021-12-31 C008999 ROXIE, Distribution, Unattended 2021-01-012021-12-31 C008999 FLORA, Distribution, Unattended 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember Rankin 115kV Sub - Add Line Bay 2021-12-31 C008999 Baxter Wilson Un 1 315 2021-01-012021-12-31 C008999 HAINING ROAD, Distribution, Unattended 2021-12-31 C008999 JACKSON/TREATMENT PLANT, Distribution, Unattended 2021-12-31 C008999 Power Management Rider Under-Recovery MPSC Docket No. 2014-UN-132 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMemberferc:PayrollTaxMember 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember 2020 - SOUTHAVEN - PLUM POINT - CHU 2021-12-31 C008999 SILVER CREEK, Distribution, Unattended 2021-12-31 C008999 ferc:ElectricUtilityMember Relocate Facilities W Capitol St 2021-12-31 C008999 HER - New Desoto Service Center 2021-01-012021-12-31 C008999 Derivative Instruments and Hedging Activities 2021-01-012021-12-31 C008999 BELZONI, Distribution, Unattended 2021-12-31 C008999 Independence Coal 2021-01-012021-12-31 C008999 ferc:NovemberMember Entergy Mississippi, LLC 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember SPO EMISunflowerCoSolarBOTTransactn 2021-01-012021-12-31 C008999 Independence Un 1 312 2021-01-012021-12-31 C008999 SUNNYBROOK, Distribution, Unattended 2021-12-31 C008999 Grand Gulf Over-Recovery MPSC Docket No. 1984-UN-4620 2020-12-31 C008999 Allowances Usedferc:SulfurDioxideMember 2021-01-012021-12-31 C008999 GLOSTER, Distribution, Unattended 2021-01-012021-12-31 C008999 Deferred rebate 2021-01-012021-12-31 C008999 RAYMOND, Distribution, Unattended 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember See Footnote 2020-12-31 C008999 ROLLING FORK, Distribution, Unattended 2021-12-31 C008999 Deposit Alternative Pay 2021-01-012021-12-31 C008999 ScheduleTransmissionOfElectricityByIsoOrRtoAbstract 2021-01-012021-12-31 C008999 LED-2 LED Street and Area  Lighting 2021-01-012021-12-31 C008999 GETWELL, BYHALIA 230KV LN 241 [2341], Steel Pole, 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember WINONA-SAWYER RD-BIEWER LUMBER-EXTE 2021-12-31 C008999 GETWELL, TWINKLETOWN 230KV LN 236 [5007], Single Concr, 1272 ACSR 2021-01-012021-12-31 C008999 Distribution 369.1 2021-01-012021-12-31 C008999 Other 2020-01-012020-12-31 C008999 Power Generation Fleet Training Plaferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 MOORHEAD, Distribution, Unattended 2021-01-012021-12-31 C008999 MIDNIGHT, Distribution, Unattended 2021-01-012021-12-31 C008999 CLARKSDALE, Distribution, Unattended 2021-12-31 C008999 CHARITY CHURCH/JACKSON, Distribution, Unattended 2021-12-31 C008999 2020 - MADISON - CANTON - 6C07 - QF 2021-01-012021-12-31 C008999 Byram Replace Breaker FJ04ferc:ElectricUtilityMember 2021-12-31 C008999 Accumulated Miscellaneous Operating Provisions (Account 2284) 2021-01-012021-12-31 C008999 ferc:NitrogenOxideMember 2020-12-31 C008999 RALEIGH, Distribution, Unattended 2021-01-012021-12-31 C008999 DELTA SWYD, Transmission, Unattended 2021-12-31 C008999 MENDENHALL, Distribution, Unattended 2021-12-31 C008999 HERNANDO - 251 HWY 51 N - ASSOCIATE 2021-01-012021-12-31 C008999 SL-37 Municipal Street Lighting 2021-01-012021-12-31 C008999 3.85% Series 2 2021-12-31 C008999 Distribution 362 2021-01-012021-12-31 C008999 2021-01-012021-09-30 C008999 Civil, Political, and Related Expenses (Account 4264)ferc:DirectPayrollDistributionMember 2021-01-012021-12-31 C008999 Delta Common 311_RES 2021-01-012021-12-31 C008999 Choctaw Generating Station Under-Recovery MPSC Docket No. 2018-UN-205 - Amort April 2021-March 2022 2021-12-31 C008999 Other 2020-01-012020-12-31 C008999 GM-39-3E08-REBUILD 3PH-NURSING HOMEferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 MISO Sch 1 Sched/Sys Ctrl/Disp 2021-01-012021-12-31 C008999 EML C Spire - Northern Routeferc:ElectricUtilityMember 2021-12-31 C008999 Qualified Pension Settlement Cost Deferral MPSC Docket No. 2020-UA-91 Amort 130 months beg Oct 2020 2020-12-31 C008999 Attala 2021-12-31 C008999 FONDREN/JACKSON, Distribution, Unattended 2021-12-31 C008999 Rex Brown Unit 1 311_RES 2021-01-012021-12-31 C008999 ferc:CapitalContributionMember EMI New Nuclear, LLC 2020-12-31 C008999 Ad Valorem Tax Adjustment Rider MPSC Docket No. 2014-UN-132 2021-12-31 C008999 AMI - DMS/OMS - Software - Rel 4-5 2021-01-012021-12-31 C008999 Horn Lake-Nail Road-Reiner Developmferc:ElectricUtilityMember 2021-12-31 C008999 ferc:OtherProductionPlantMemberferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 2022-Vicksburg-Glass Roadferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 Other production plantferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 LIBERTY, Distribution, Unattended 2021-01-012021-12-31 C008999 Qualified Pension Settlement Cost Deferral MPSC Docket No. 2020-UA-91 Amort 130 months beg Oct 2020 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember T&D 2021 Rankin UG  - N1 2021-12-31 C008999 Common equity distributions 2020-01-012020-12-31 C008999 FLI-SENATOBIA NETWORK-SENATOBIA-1H0ferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 FANNIN ROAD, Distribution, Unattended 2021-01-012021-12-31 C008999 20210315-5351, 44270, ER21-1429 2021-01-012021-12-31 C008999 T&D - Catlett 230kv Sub - Substatio 2021-01-012021-12-31 C008999 ferc:ExciseTaxMemberferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 State Use Tax, Sales And Use Tax, ,ferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 CANTON, SOUTH CANTON 230KV LN 230 [6185], Steel Pole, 1272 ACSR 2021-01-012021-12-31 C008999 VICKSBURG/EAST, Distribution, Unattended 2021-12-31 C008999 REX BROWN SES, RAY BRASWELL 230KV LN 205 [7100], Wood H-Frame, 1272 ACSR 2021-01-012021-12-31 C008999 See Footnote Detail 2021-01-012021-12-31 C008999 MENDENHALL, Distribution, Unattended 2021-01-012021-12-31 C008999 2020 Planning SE17-012A Regs/RC RREferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 SOUTH JACKSON, RAY BRASWELL 230KV LN 206 [7370], Single Concr, 1272 ACSR 2021-01-012021-12-31 C008999 Choctaw Generating Station Over-Recovery - MPSC Docket No. 2018-UN-205 2021-01-012021-12-31 C008999 ferc:PayrollTaxMember 2021-01-012021-12-31 C008999 WALLS, Distribution, Unattended 2021-12-31 C008999 Add Ckt. 9A06  to Poleline for Seco 2021-01-012021-12-31 C008999 Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff, Docket No. ER20-1449 2021-01-012021-12-31 C008999 3.5% Series 2 2021-12-31 C008999 Gerald Andrus 312 2021-01-012021-12-31 C008999 Power Management Rider Over-Recovery MPSC Docket 2021-12-31 C008999 10%ferc:ElectricUtilityMember 2020-12-31 C008999 Hinds Unit 2 344 2021-01-012021-12-31 C008999 2022-Vicksburg-Glass Roadferc:ElectricUtilityMember 2021-12-31 C008999 ferc:ElectricUtilityMember Jackson, S: E&D J4674 Bay Upgrade 2021-12-31 C008999 CATLETT, SOUTH CANTON 230 KV LN 244 [2392], Steel Pole, 2021-01-012021-12-31 C008999 Transmission 355 2021-01-012021-12-31 C008999 FAYETTE, Distribution, Unattended 2021-01-012021-12-31 C008999 2020 Planning RK20-010V Rebuild R2ferc:ElectricUtilityMember 2021-12-31 C008999 4.52% Series 2021-12-31 C008999 Delta Common 312_RES 2021-01-012021-12-31 C008999 SPRING RIDGE ROAD, Distribution, Unattended 2021-01-012021-12-31 C008999 ferc:FranchiseTaxMember 2021-01-012021-12-31 C008999 MISO Financial Transmission Rights Mark-to-Market 2020-12-31 C008999 Franklin: AT1 Cph/Spare Life Extend 2021-01-012021-12-31 C008999 MEADVILLE, Distribution, Unattended 2021-12-31 C008999 ferc:SeveranceTaxMemberferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 Mississippi Power & Light Company 2021-12-31 C008999 Highway 51 Warehouse Relocationferc:ElectricUtilityMember 2021-12-31 C008999 All 115 kV Lines, , , 2021-01-012021-12-31 C008999 Entergy Services, LLC, Income Tax, , 2021-01-012021-12-31 C008999 C-29 Large General Service 2021-01-012021-12-31 C008999 RIDGELAND, Distribution, Unattended 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember FC20M036 - FOCUS - 8F05 - FJ669 2021-12-31 C008999 Digital LIHEAP 2021-01-012021-12-31 C008999 MIDWAY RD IMPROVEMENT PROJECT - CLI 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember Jackson - Hwy LED Lighting 2021-01-012021-12-31 C008999 General Plant 395 2021-01-012021-12-31 C008999 Normal and Surtax @ 21% 2021-01-012021-12-31 C008999 Federal Income Tax, Federal Tax, , 2021-12-31 C008999 ferc:ElectricUtilityMemberferc:LocalTaxMember 2021-01-012021-12-31 C008999 GS-298X 2021-01-012021-12-31 C008999 EMI Sunflower County SolarOversightferc:ElectricUtilityMember 2021-12-31 C008999 B(4), CEATI International 2021-01-012021-12-31 C008999 ATTALA, Distribution, Unattended 2021-12-31 C008999 AIRPORT/JACKSON, Distribution, Unattended 2021-01-012021-12-31 C008999 Bowling Green - Durant 115kV CAP 2021-01-012021-12-31 C008999 Rex Brown Unit 1 312 2021-01-012021-12-31 C008999 Fuel Stock Exp Undistributed (Account 152) 2021-01-012021-12-31 C008999 See Footnote Detail 2021-01-012021-12-31 C008999 FC21M010 - FOCUS - FP02 - FP02ferc:ElectricUtilityMember 2021-12-31 C008999 HN1 - Hinds LTSA Capital 2021-01-012021-12-31 C008999 ferc:AfterThreeYearsMemberferc:NitrogenOxideMember 2021-01-012021-12-31 C008999 Independence Un 2 312 2021-01-012021-12-31 C008999 Contra UA 397.1_RES 2021-01-012021-12-31 C008999 ferc:OtherUseTaxMember 2021-01-012021-12-31 C008999 Entergy Services, LLC, Other Allocated Tax, , 2021-01-012021-12-31 C008999 2021-01-012021-06-30 C008999 2.55% Series 2021-01-012021-12-31 C008999 General Plant 391.3 2021-01-012021-12-31 C008999 Byram replace FJ05 & RTU Grid Mod 2021-01-012021-12-31 C008999 CANTON, Distribution, Unattended 2021-12-31 C008999 ferc:NextTwelveMonthsMemberferc:SulfurDioxideMember 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember 2020-01-012020-12-31 C008999 Kimberly A. Fontan 2021-01-012021-12-31 C008999 Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff, Docket No. ER19-747 2021-01-012021-12-31 C008999 ROBINSON ROAD/JACKSON, Distribution, Unattended 2021-01-012021-12-31 C008999 FICA, Federal Tax, , 2021-12-31 C008999 B(4), Environmental Research 2021-01-012021-12-31 C008999 Amortization of debt discount and expense and premium on debt and amortization of loss on reacquired debt 2021-01-012021-12-31 C008999 ISES Acquisition Adjustment 2021-12-31 C008999 Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff, Docket No. ER16-227 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMemberferc:ElectricPlantInServiceMember 2020-12-31 C008999 ferc:OtherTaxMember 2020-12-31 C008999 EDWARDS, Distribution, Unattended 2021-12-31 C008999 MPSC  - Docket No. 2008-UN-381 - Power Management Rider Expense 2021-12-31 C008999 Ad Valorem Tax - AR, Other Ad Valorem Tax, , 2021-12-31 C008999 ferc:ElectricUtilityMember Add Ckt. 9A06  to Poleline for Seco 2021-12-31 C008999 ferc:ElectricUtilityMemberferc:OtherUseTaxMember 2021-01-012021-12-31 C008999 ferc:OtherPropertyTaxMember 2021-01-012021-12-31 C008999 GM-39-3R02-RC7 Capacitor removal Hiferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 HAZLEHURST, Distribution, Unattended 2021-01-012021-12-31 C008999 VICKSBURG, Distribution, Unattended 2021-12-31 C008999 , , , 2021-01-012021-12-31 C008999 Solar Hinds County 341 2021-01-012021-12-31 C008999 Hinds Unit 2 343 2021-01-012021-12-31 C008999 CARTHAGE (MS), Distribution, Unattended 2021-12-31 C008999 ATTALA PLANT, Transmission, Unattended 2021-12-31 C008999 Gerald Andrus 2021-12-31 C008999 Mark-to-Market 2021-01-012021-12-31 C008999 ferc:OtherAllocatedTaxMember 2021-01-012021-12-31 C008999 YANDELL RD, Distribution, Unattended 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember Schlater 115kV Station: Add Brkrs 2021-12-31 C008999 GERALD ANDRUS SES SWYD, Transmission, Unattended 2021-01-012021-12-31 C008999 Defined Benefit Pension & Other Post Retirement Plans 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember 2020 - Jackson North - Jackson Nort 2021-12-31 C008999 JOHNS MANVILLE, Distribution, Unattended 2021-01-012021-12-31 C008999 SAISO Replacement 2021-01-012021-12-31 C008999 Delta Common 315_RES 2021-01-012021-12-31 C008999 Oil Gerald Andrus 2021-01-012021-12-31 C008999 ferc:LandAndRightsMember Land and Land Rights Under $250,000 2021-12-31 C008999 State Income Tax, State Tax, , 2020-12-31 C008999 ferc:IncomeTaxMember 2021-01-012021-12-31 C008999 EDF Trading North America, LLC , OS , 2021-01-012021-12-31 C008999 ferc:MarchMember Entergy Mississippi, LLC 2021-01-012021-12-31 C008999 Other working capital 2020-01-012020-12-31 C008999 ScheduleCapitalStockExpenseAbstract 2021-01-012021-12-31 C008999 Franklin-GGNS 500Kv Phase Swaferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 GASES, INDIANOLA 230KV LN 203 [5580], Wood H-Frame, 1272 ACSR 2021-01-012021-12-31 C008999 JACKSON/NORTHEAST, Distribution, Unattended 2021-12-31 C008999 General Plant 389.2 2021-01-012021-12-31 C008999 DSL-16 Directional Security  Lighting 2021-01-012021-12-31 C008999 Gerald Andrus 311 2021-01-012021-12-31 C008999 Grand Gulf Over-Recovery MPSC Docket No. 1984-UN-4620 2021-01-012021-12-31 C008999 Roderick K. West - Group President Utility Operations 2021-01-012021-12-31 C008999 ENID, Distribution, Unattended 2021-01-012021-12-31 C008999 COMO, Distribution, Unattended 2021-12-31 C008999 AMI Sales and Rev BIEferc:ElectricUtilityMember 2021-12-31 C008999 2020 - SOUTHAVEN - PLUM POINT - CHU 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember Florence: Capacitors (54) on CapBk 2021-01-012021-12-31 C008999 IP-33 Ice Manufacturing Plant Power 2021-01-012021-12-31 C008999 QF-18 2021-01-012021-12-31 C008999 Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff, Docket No. ER17-827 2021-01-012021-12-31 C008999 Entergy Services, LLC, Income Tax, , 2021-12-31 C008999 3.1% Series 2021-01-012021-12-31 C008999 Byram Replace Breaker FJ04ferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 2021-Magee-Mendenhall-Relocate Faci 2021-01-012021-12-31 C008999 Greenwood-Itta Bena 115Kv Cut-Inferc:ElectricUtilityMember 2021-12-31 C008999 GM-Guild 33-GK01-Rebuild-Brookwoodferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 GALLMAN, Distribution, Unattended 2021-12-31 C008999 ferc:NitrogenOxideMember 2021-12-31 C008999 ferc:StateTaxMember 2020-12-31 C008999 Roderick K. West 2021-01-012021-12-31 C008999 Midcontinent Indepedent System Operator (MISO) FERC Electric Tariff - Fifth Revised Volume 1, Docket No. ER13-948 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember Other Debit or Cr. Items (Describe, details in footnote):ferc:ElectricPlantInServiceMember 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember 2020 - Madison-Yandell-GY01 & GY05- 2021-12-31 C008999 ScheduleExtraordinaryPropertyLossesAbstract 2021-01-012021-12-31 C008999 Asset Retirement Obligation - Coal 2020-12-31 C008999 LAKEOVER, HINDS BLACKSTART UNIT INTERCONNECT 230KV LN 242 [2342], Steel Pole, 954 ACSR 2021-01-012021-12-31 C008999 Estimated Consolidated Income Tax Allocated - See Footnote Detail - applicable for 1/1/21 - 12/31/21 2021-01-012021-12-31 C008999 0 2021-01-012021-12-31 C008999 FOREST HILL/JACKSON, Distribution, Unattended 2021-12-31 C008999 2020 Planning RK20-010V Rebuild R2 2021-01-012021-12-31 C008999 Distribution 370 2021-01-012021-12-31 C008999 ferc:SeptemberMember 0 2021-01-012021-12-31 C008999 UFL-16 Urban Flood Lighting 2021-01-012021-12-31 C008999 EMI 2021 Dec Storm ferc:ElectricUtilityMember 2021-12-31 C008999 ferc:SeveranceTaxMember 2021-12-31 C008999 BATESVILLE [MS], Transmission, Unattended 2021-12-31 C008999 WALLS, Distribution, Unattended 2021-01-012021-12-31 C008999 B(1), EPRI dues 4 2021-01-012021-12-31 C008999 ferc:NitrogenOxideMemberferc:ThreeYearsMember 2021-01-012021-12-31 C008999 Non-Qualified Pension funded status 2021-12-31 C008999 YAZOO CITY MUNICIPAL SS, Transmission, Unattended 2021-01-012021-12-31 C008999 Andrew S. Marsh - Executive Vice President and Chief Financial Officer 2021-01-012021-12-31 C008999 Downtown Jackson - Replace 500 KVAferc:ElectricUtilityMember 2021-12-31 C008999 ferc:MiscellaneousOtherTaxMember 2021-01-012021-12-31 C008999 GA1 WaterWallTube & Furn Hopp Bottoferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 The Light, Heat and Water Company of Jackson, Mississippi 2021-12-31 C008999 Fannin Rd: add Fdr Bkr Amp Transducferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 ServiceNow Enhancementsferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 T&D - Flora Add Transformer - Northferc:ElectricUtilityMember 2021-12-31 C008999 CLEVELAND/SOUTH, Distribution, Unattended 2021-01-012021-12-31 C008999 2020 - VICKSBURG - VICKSBURG EAST - 2021-01-012021-12-31 C008999 ferc:FederalTaxMember 2021-01-012021-12-31 C008999 Utility Data Warehouse Plusferc:ElectricUtilityMember 2021-12-31 C008999 ferc:SulfurDioxideMember 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember Madison-Hwy 43-Expedition Point Dev 2021-01-012021-12-31 C008999 HR leadership development 2021-01-012021-12-31 C008999 ENID, Distribution, Unattended 2021-12-31 C008999 A1A - GE LTSA Budget Cap 2020-2024 2021-01-012021-12-31 C008999 SPENCER POTASH, Distribution, Unattended 2021-01-012021-12-31 C008999 Greenville Replace Breaker 3E08, J4ferc:ElectricUtilityMember 2021-12-31 C008999 Miscellaneous Current and Accrued Assets (Account 174)ferc:DirectPayrollDistributionMember 2021-01-012021-12-31 C008999 Hazlehurst add circuit switchersferc:ElectricUtilityMember 2021-12-31 C008999 VICKSBURG/SOUTHEAST, Distribution, Unattended 2021-12-31 C008999 Fannin Rd: add Fdr Bkr Amp Transduc 2021-01-012021-12-31 C008999 2020 - RANKIN - AIRPORT - 6A04 - 55ferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 BOZEMAN ROAD, Distribution, Unattended 2021-12-31 C008999 ferc:FuelTaxMember 2021-12-31 C008999 LAKEOVER EHV, Transmission, Unattended 2021-12-31 C008999 JONESTOWN SS, Transmission, Unattended 2021-12-31 C008999 Asset Retirement Obligation - Coal 2021-01-012021-12-31 C008999 ferc:AprilMember 0 2021-01-012021-12-31 C008999 PICKENS, Distribution, Unattended 2021-12-31 C008999 TUNICA 230/115 SUB, Transmission, Unattended 2021-12-31 C008999 NATCHEZ/INDUSTRIAL PARK, Distribution, Unattended 2021-12-31 C008999 ferc:ElectricUtilityMember Clinton - Phase 1 / District 6-City 2021-12-31 C008999 Other Accounts (Specify, details in footnote): 2021-01-012021-12-31 C008999 Independence Un 2 314 2021-01-012021-12-31 C008999 RANKIN, Transmission, Unattended 2021-01-012021-12-31 C008999 Employment Litigation 2021-12-31 C008999 Rankin -- Permanent Svc to Communitferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 Gas Choctaw 2021-01-012021-12-31 C008999 General Plant 398 2021-01-012021-12-31 C008999 Deposit Alternative Payferc:ElectricUtilityMember 2021-12-31 C008999 Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff, Docket No. ER21-2169 2021-01-012021-12-31 C008999 Franchise - City, Local Tax, , 2020-12-31 C008999 FICA, Federal Tax, , 2021-01-012021-12-31 C008999 ferc:FranchiseTaxMember 2021-12-31 C008999 State Unemployment Tax, Unemployment Tax, , 2021-01-012021-12-31 C008999 Horn Lake-MS Hwy 301-Yazoo Developm 2021-01-012021-12-31 C008999 Nesbit-Laughter Road-Bridgforth Pro 2021-01-012021-12-31 C008999 Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff, Docket No. ER18-1260 2021-01-012021-12-31 C008999 Baxter Wilson Un 1 316 2021-01-012021-12-31 C008999 SOUTH JACKSON, RAY BRASWELL 230KV LN 217 [7375], Steel Pole, 1272 ACSR 2021-01-012021-12-31 C008999 Andrew S. Marsh 2021-01-012021-12-31 C008999 ferc:OtherLicenseAndFeesTaxMember 2021-01-012021-12-31 C008999 Franklin-GGNS 500Kv Phase Swa 2021-01-012021-12-31 C008999 Qualified Pension Settlement Cost Deferral MPSC Docket No. 2020-UA-91 Amort 120 months beg July 2021 2021-01-012021-12-31 C008999 Long-Term Incentive Plan 2021-12-31 C008999 MADISON, Distribution, Unattended 2021-01-012021-12-31 C008999 MCCOMB, Distribution, Unattended 2021-12-31 C008999 See Footnote Detailferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 B(2), Edison Electric Institute 2021-01-012021-12-31 C008999 2020 Planning CL20-005V Rebuild R1ferc:ElectricUtilityMember 2021-12-31 C008999 See Footnote Detail 2021-01-012021-12-31 C008999 Distribution 361 2021-01-012021-12-31 C008999 Section 263A 2021-01-012021-12-31 C008999 Income Taxes 2020-12-31 C008999 JACKSON/WATERWORKS, Distribution, Unattended 2021-12-31 C008999 Relocate Facilities W Capitol St 2021-01-012021-12-31 C008999 ferc:OtherPropertyTaxMember 2020-12-31 C008999 3.85% Series 1 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember MS Trans Off/Stor Facility Design 2021-12-31 C008999 ferc:OtherPropertyTaxMemberferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 Indianola: E&D J3110 Xfmr Bay Upgdferc:ElectricUtilityMember 2021-12-31 C008999 CLEVELAND [MS], Distribution, Unattended 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember Nesbit-Laughter Road-Bridgforth Pro 2021-01-012021-12-31 C008999 ferc:OctoberMember Entergy Mississippi, LLC 2021-01-012021-12-31 C008999 Hinds Unit 1 342 2021-01-012021-12-31 C008999 Section 263A research - tax services 2021-01-012021-12-31 C008999 Small Residential Generation , OS , 2021-01-012021-12-31 C008999 Entergy Services, LLC, Income Tax, , 2020-12-31 C008999 RFL-16 Rural Flood Lighting 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember Horn Lake-MS Hwy 301-Yazoo Developm 2021-01-012021-12-31 C008999 CHOCTAW, Transmission, Unattended 2021-12-31 C008999 ferc:RealEstateTaxMember 2020-12-31 C008999 ferc:DirectPayrollDistributionMember Stores Expense Undistributed (Account 163) 2021-01-012021-12-31 C008999 BELZONI, Distribution, Unattended 2021-01-012021-12-31 C008999 MPSC  - Docket No. 2018-UN-205 - EML Formula Rate Plan 2021-12-31 C008999 Compliance Deductionferc:SulfurDioxideMember 2021-01-012021-12-31 C008999 Amortization of debt discount and expense and premium on debt and amortization of loss on reacquired debt 2020-01-012020-12-31 C008999 GRANTS FERRY, Distribution, Unattended 2021-01-012021-12-31 C008999 Regulatory Commission, Other Taxes, , 2021-01-012021-12-31 C008999 PICKENS, Transmission, Unattended 2021-01-012021-12-31 C008999 Directors meetings and expenses 2021-01-012021-12-31 C008999 C6PPTM2110: Brookhaven - Wesson 115ferc:ElectricUtilityMember 2021-12-31 C008999 Non Income Tax, Miscellaneous Other Tax, ,ferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 Independence 2021-12-31 C008999 ferc:ElectricUtilityMember Florence: Capacitors (54) on CapBk 2021-12-31 C008999 COMO, Distribution, Unattended 2021-01-012021-12-31 C008999 SENATOBIA, Distribution, Unattended 2021-12-31 C008999 ferc:TwoYearsMemberferc:NitrogenOxideMember 2021-12-31 C008999 WEBB, Distribution, Unattended 2021-01-012021-12-31 C008999 RAYMOND, Distribution, Unattended 2021-12-31 C008999 TWINKLETOWN, Distribution, Unattended 2021-01-012021-12-31 C008999 Non Income Tax, Miscellaneous Other Tax, , 2020-12-31 C008999 GM-39-3R02-RC7 Capacitor removal Hi 2021-01-012021-12-31 C008999 2021 FOCUS FC21M021 Natchez 8F05 Roferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 Natchez 310.2 2021-01-012021-12-31 C008999 SARDIS, Distribution, Unattended 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember Raleigh 115kV Sub - Add 2nd Transf 2021-12-31 C008999 ferc:ElectricUtilityMember DeSoto County-Ross Meadows Land-M&R 2021-12-31 C008999 Income Taxes 2021-12-31 C008999 Mississippi Power & Light Co.ferc:CapitalContributionMember 2021-12-31 C008999 ALGS-10 / Other 2021-01-012021-12-31 C008999 Distribution 370.15 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember Gallatin: rpl FX20 & add FX10 Fdr  2021-12-31 C008999 GM-Guild 33-FA06-Rebuild-Cleary Rdferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 INVERNESS, Distribution, Unattended 2021-12-31 C008999 BEECH GROVE SS, Transmission, Unattended 2021-12-31 C008999 MISO Various Various 2021-01-012021-12-31 C008999 Other expenses incurred in connection wiht various filings before the FERC 2021-01-012021-12-31 C008999 Getwell-Twinkletown 230kV Cut-In 2021-01-012021-12-31 C008999 Unit Power Cost Recovery Rider Over-Recovery MPSC Docket No. 2014-UN-132 2021-01-012021-12-31 C008999 Downtown Jackson - Replace 500 KVAferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 Section 263A 2021-12-31 C008999 ferc:OtherAllocatedTaxMember 2020-12-31 C008999 ferc:ElectricUtilityMember WINONA-SAWYER RD-BIEWER LUMBER-EXTE 2021-01-012021-12-31 C008999 ferc:SchedulingSystemControlAndDispatchMember 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember Greenville SE Install circuit sw. o 2021-01-012021-12-31 C008999 Other Debit or Cr. Items (Describe, details in footnote): 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember Brookhaven Upgrade Transformer 2021-01-012021-12-31 C008999 ferc:OtherTaxMemberferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 Midnight: rpl ABS J0348 & Steel Bus 2021-01-012021-12-31 C008999 RULEVILLE, Distribution, Unattended 2021-12-31 C008999 GRENADA/SOUTH, Distribution, Unattended 2021-01-012021-12-31 C008999 BATESVILLE [MS], Transmission, Unattended 2021-01-012021-12-31 C008999 ferc:OtherTaxesAndFeesMemberferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 Ad Valorem Tax - MS, Other Ad Valorem Tax, , 2020-12-31 C008999 A(3) B(4), Advanced meters 2021-01-012021-12-31 C008999 Schlater 115kV Station: Add Brkrs 2021-01-012021-12-31 C008999 Deferred Attorney General Litigation Costs MPSC Docket No. 2009-UN-388 Amort 6 years beg April 2020 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember T&D - Flora Add Transformer - West 2021-01-012021-12-31 C008999 T&D - Flora Add Transformer - West 2021-01-012021-12-31 C008999 ScheduleNuclearFuelMaterialsAbstract 2021-01-012021-12-31 C008999 System Energy Resources, Inc. , OS , 2021-01-012021-12-31 C008999 Attala Unit 1 345 2021-01-012021-12-31 C008999 RIDGELAND, Distribution, Unattended 2021-12-31 C008999 FRANKLIN EHV, Transmission, Unattended 2021-01-012021-12-31 C008999 7% 2021-01-012021-12-31 C008999 C6PPTM2110: Brookhaven - Wesson 115ferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 WOLF CREEK, Transmission, Unattended 2021-01-012021-12-31 C008999 CHARLESTON, Distribution, Unattended 2021-01-012021-12-31 C008999 Rex Brown Common 310.2 2021-01-012021-12-31 C008999 HL-21 Public Highway & Park Lighting 2021-01-012021-12-31 C008999 State Excise Tax, Excise Tax, , 2020-12-31 C008999 EML:115-4.16 | 12.5MVA | JTreatment 2021-01-012021-12-31 C008999 Power Generation Fleet Training Pla 2021-01-012021-12-31 C008999 JACKSON/SOUTH, Distribution, Unattended 2021-01-012021-12-31 C008999 2021 SHN JXSNSW-KINGSW - 2 RCs 2021-01-012021-12-31 C008999 Transmission 358 2021-01-012021-12-31 C008999 GS-298 MS Gen. Lghtg & Pwr Muni. Service 2021-01-012021-12-31 C008999 HERNANDO - 251 HWY 51 N - ASSOCIATEferc:ElectricUtilityMember 2021-12-31 C008999 ScheduleCommonUtilityPlantAndExpensesAbstract 2021-01-012021-12-31 C008999 TILLATOBA, BATESVILLE 230KV LN 208 [5840], Wood H-Frame, 1272 ACSR 2021-01-012021-12-31 C008999 Utility Data Warehouse Plusferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 ferc:CapitalContributionMember EMI New Nuclear, LLC 2021-01-012021-12-31 C008999 Rex Brown Unit 1 315_RES 2021-01-012021-12-31 C008999 Other general and intangible plant 2021-01-012021-12-31 C008999 Attala Common 344 2021-01-012021-12-31 C008999 Transmission 356.1 2021-01-012021-12-31 C008999 FC21M010 - FOCUS - FP02 - FP02ferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 GALLMAN, Distribution, Unattended 2021-01-012021-12-31 C008999 Gerald Andrus Gas 2021-01-012021-12-31 C008999 Greenville Replace Breaker 3E08, J4 2021-01-012021-12-31 C008999 TILLATOBA, SOUTH GRENADA 230KV LN 237 [2337], Steel Pole, 1272 ACSR 2021-01-012021-12-31 C008999 GLOSTER, Distribution, Unattended 2021-12-31 C008999 HERNANDO, Distribution, Unattended 2021-12-31 C008999 Hollandale: E&D 3J22 & 02 Bkr Rpl 2021-01-012021-12-31 C008999 ferc:PayrollTaxMember 2020-12-31 C008999 ferc:ElectricUtilityMember Advanced DMS 2021-01-012021-12-31 C008999 Raleigh 115kV Sub - Add 2nd Transf 2021-01-012021-12-31 C008999 Distribution 369.2 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember SPO EMISunflowerCoSolarBOTTransactn 2021-12-31 C008999 Other 2021-12-31 C008999 Deferred rebate 2020-12-31 C008999 Asset Retirement Obligation - Fossil 2020-12-31 C008999 Jackson, W: rpl RTUferc:ElectricUtilityMember 2021-12-31 C008999 BRANDON, Distribution, Unattended 2021-01-012021-12-31 C008999 BWSES, STERLINGTON (MS/LA ST LN) 500KV LN 503 (OPCO TIE) [5200], Steel Tower, 3070 ACSR 2021-01-012021-12-31 C008999 Hollandale: E&D 3J22 & 02 Bkr Rplferc:ElectricUtilityMember 2021-12-31 C008999 Indianola-Itta Bena 115kvferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 GETWELL, Distribution, Unattended 2021-12-31 C008999 ROSEDALE [MS], Distribution, Unattended 2021-12-31 C008999 MP-22 Municipal Pumping Power Service 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember 2021-12-31 C008999 VICKSBURG/OPENWOOD, Distribution, Unattended 2021-01-012021-12-31 C008999 AMI - DMS/OMS - Software - Rel 4-5ferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 Gerald Pipelines 310.2 2021-01-012021-12-31 C008999 GM-39-3E08-REBUILD 3PH-NURSING HOMEferc:ElectricUtilityMember 2021-12-31 C008999 Florence: Capacitors (54) on CapBk 2021-01-012021-12-31 C008999 BOVINA, Distribution, Unattended 2021-01-012021-12-31 C008999 FERNWOOD, Distribution, Unattended 2021-01-012021-12-31 C008999 Distribution 368.1 2021-01-012021-12-31 C008999 GEORGETOWN [MS], Distribution, Unattended 2021-12-31 C008999 Gerald Andrus 311.1 2021-01-012021-12-31 C008999 2020-01-012020-12-31 C008999 SOUTH CANTON, YANDELL RD 230KV LN 214 [2314], Wood H-Frame, 1272 ACSR 2021-01-012021-12-31 C008999 JOHNS MANVILLE, Distribution, Unattended 2021-12-31 C008999 SPO EMISunflowerCoSolarBOTTransactn 2021-01-012021-12-31 C008999 Travel to reimburse project 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember Corporate Franchise Tax-MS, Franchise Tax, , 2021-01-012021-12-31 C008999 ferc:RealEstateTaxMember 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember Lakeover-Hinds 230kV CAP 2021-12-31 C008999 Choctaw 2021-01-012021-12-31 C008999 Hinds Unit 1 343 2021-01-012021-12-31 C008999 ELLIOTT SS, Transmission, Unattended 2021-01-012021-12-31 C008999 ferc:PenaltyTaxMember 2021-12-31 C008999 2020 - RANKIN - AIRPORT - 6A04 - 55ferc:ElectricUtilityMember 2021-12-31 C008999 BOWLING GREEN SS, Transmission, Unattended 2021-01-012021-12-31 C008999 Choctaw purchase - escrow funds 2020-12-31 C008999 HWY-2020-GM01-DF400-BOZEMAN RD OH 1 2021-01-012021-12-31 C008999 LAKE CASTLE, Distribution, Unattended 2021-01-012021-12-31 C008999 3% 2021-01-012021-12-31 C008999 2.85% Series 2021-12-31 C008999 ferc:AdValoremTaxMember 2021-12-31 C008999 YAZOO CITY SS, Distribution, Unattended 2021-01-012021-12-31 C008999 Distribution 370.1 2021-01-012021-12-31 C008999 KOSCIUSKO, Distribution, Unattended 2021-12-31 C008999 Receipts & Sales, Other State Tax, , 2021-12-31 C008999 ferc:OtherUtilityOrNonutilityMember Mississippi ITC 2021-01-012021-12-31 C008999 Increases (Decreases) in Other Paid-In Capital 2021-01-012021-12-31 C008999 RTO 382 2021-01-012021-12-31 C008999 CATLETT, Distribution, Unattended 2021-12-31 C008999 EMI Sunflower County SolarOversightferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 ferc:Quarter1Member 0 2021-01-012021-12-31 C008999 TYLERTOWN, Distribution, Unattended 2021-12-31 C008999 RANKIN INDTRL./JACKSON, Distribution, Unattended 2021-01-012021-12-31 C008999 GRAND GULF DISTRIBUTION, Distribution, Unattended 2021-12-31 C008999 Entergy Mississippi, LLC 2021-01-012021-12-31 C008999 ferc:FederalInsuranceTaxMember 2020-12-31 C008999 Purchases/Transfers:ferc:CurrentYearMemberferc:SulfurDioxideMember 2021-01-012021-12-31 C008999 YANDELL RD, Distribution, Unattended 2021-12-31 C008999 LAKEOVER EHV, Transmission, Unattended 2021-01-012021-12-31 C008999 Corporate Franchise Tax-MS, Franchise Tax, , 2020-12-31 C008999 MISO Sch 2 Reactive 2021-01-012021-09-30 C008999 ferc:ElectricUtilityMember 7% 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember 2021 - Midstate - Kosciusko - Insta 2021-12-31 C008999 GM-39-3E08-REBUILD 3PH-NURSING HOME 2021-01-012021-12-31 C008999 Distribution 365.2 2021-01-012021-12-31 C008999 TUNICA, RITCHIE 230KV LN 212 [7490], Steel Tower, 1272 ACSR 2021-01-012021-12-31 C008999 ferc:FederalTaxMember 2021-12-31 C008999 State Excise Tax, Excise Tax, , 2021-12-31 C008999 Joseph T. Henderson 2021-01-012021-12-31 C008999 Franchise - City, Local Tax, , 2021-12-31 C008999 Build Pine Tree 230/12.47kV Subferc:ElectricUtilityMember 2021-12-31 C008999 2021 RANKIN MORTON 6R02 55Q0022 2021-01-012021-12-31 C008999 Energy Efficiency Rider Under-Recovery 2020-12-31 C008999 Baxter Wilson Gas 2021-01-012021-12-31 C008999 Natchez 316_RES 2021-01-012021-12-31 C008999 Attala Common 341 2021-01-012021-12-31 C008999 Crenshaw: Add Circuit Switcherferc:ElectricUtilityMember 2021-12-31 C008999 ferc:ElectricUtilityMember EML: 115-13.8 | 20MVA (Marvell) 2021-12-31 C008999 ferc:ElectricUtilityMember BWSES: J2200 AT1 Spare Life Extend 2021-12-31 C008999 Baxter Wilson Un 1 312 2021-01-012021-12-31 C008999 General Plant 391.2 2021-01-012021-12-31 C008999 FC21M010 - FOCUS - FP02 - FP02 2021-01-012021-12-31 C008999 Franklin 500kV Reconfigurationferc:ElectricUtilityMember 2021-12-31 C008999 Natchez 312_RES 2021-01-012021-12-31 C008999 MISO Sch 2 Reactive 2021-01-012021-06-30 C008999 General Plant 393 2021-01-012021-12-31 C008999 All 230 kV Lines, , , 2021-01-012021-12-31 C008999 Other 2021-01-012021-12-31 C008999 MARKS, Distribution, Unattended 2021-12-31 C008999 Digital LIHEAPferc:ElectricUtilityMember 2021-12-31 C008999 ferc:ElectricUtilityMember 2020 Focus 6R02 FC20M051 Rankin Rou 2021-12-31 C008999 Grid Modernization Rider Over-Recovery MPSC Docket No. 2017-UN-198 2020-12-31 C008999 Payment for Purchase of Assets 2021-01-012021-12-31 C008999 Baxter Wilson 2021-12-31 C008999 Gerald Andrus 316 2021-01-012021-12-31 C008999 GREENVILLE/SOUTHEAST, Distribution, Unattended 2021-12-31 C008999 Entergy Services, LLC, Other Allocated Tax, , 2020-12-31 C008999 Transmission 354 2021-01-012021-12-31 C008999 TUNICA, Distribution, Unattended 2021-12-31 C008999 ferc:ElectricUtilityMember Franklin: AT1 Cph/Spare Life Extend 2021-12-31 C008999 SWH-20 Gen. Space and Water Heating Serv. 2021-01-012021-12-31 C008999 NEW HEBRON, Distribution, Unattended 2021-12-31 C008999 Corporate Franchise Tax-MS, Franchise Tax, , 2021-12-31 C008999 BaxterWilson Com 310.2 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMemberferc:DistributionPlantMember 2021-01-012021-12-31 C008999 Unit Power Cost Recovery Rider Over-Recovery MPSC Docket No. 2014-UN-132 2021-12-31 C008999 FOREST HILL/JACKSON, Distribution, Unattended 2021-01-012021-12-31 C008999 Corporate Franchise Tax-MS, Franchise Tax, , 2021-01-012021-12-31 C008999 EMI New Nuclear, LLC 2021-01-012021-12-31 C008999 WOODVILLE [MS], Distribution, Unattended 2021-12-31 C008999 ferc:ElectricUtilityMember Schlater 115kV Station: Add Brkrs 2021-01-012021-12-31 C008999 GREENVILLE/NORTH, Distribution, Unattended 2021-01-012021-12-31 C008999 EMI 2021 Dec Storm  2021-01-012021-12-31 C008999 Entergy Mississippi, LLCferc:JanuaryMember 2021-01-012021-12-31 C008999 Changes in money pool payable - net 2020-01-012020-12-31 C008999 RAY BRASWELL, MCKNIGHT (MS/LA ST LN) 500KV LN 504,505 (OPCO TIE) [6980], Steel Tower, 954 ACSR 2021-01-012021-12-31 C008999 BaxterWilson Com 311.1 2021-01-012021-12-31 C008999 SPENCER POTASH, Distribution, Unattended 2021-12-31 C008999 ferc:AdValoremTaxMember 2020-12-31 C008999 2020 Planning SH20-005V Getwell - Eferc:ElectricUtilityMember 2021-12-31 C008999 ferc:ElectricUtilityMember SAISO Replacement 2021-01-012021-12-31 C008999 Federal Uemployment Tax, Federal Tax, , 2021-01-012021-12-31 C008999 WOODVILLE [MS], Distribution, Unattended 2021-01-012021-12-31 C008999 Increases (Decreases) Due to Miscellaneous Paid-In Capital 2021-01-012021-12-31 C008999 ferc:ExciseTaxMember 2021-01-012021-12-31 C008999 Choctaw Generating Station Under-Recovery MPSC Docket No. 2018-UN-205 - Amort April 2021-March 2022 2021-01-012021-12-31 C008999 Federal Income Tax, Federal Tax, ,ferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 2020 Focus 6R02 FC20M051 Rankin Rou 2021-01-012021-12-31 C008999 GERALD ANDRUS SES SWYD, Transmission, Unattended 2021-12-31 C008999 EMI New Nuclear, LLC 2021-12-31 C008999 Haley R. Fisackerly 2021-01-012021-12-31 C008999 EML Public EV Charging Pilotferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 MONUMENT STREET/JACKSON, Distribution, Unattended 2021-01-012021-12-31 C008999 Snowden Park-Bld 115kV Sub-Scoping 2021-01-012021-12-31 C008999 Other expenses incurred in connection with various filings before the MPSC 2021-12-31 C008999 ferc:ElectricUtilityMember 2021 Planning CV20-002A New Build N 2021-01-012021-12-31 C008999 HAINING ROAD, Distribution, Unattended 2021-01-012021-12-31 C008999 FONDREN/JACKSON, Distribution, Unattended 2021-01-012021-12-31 C008999 FLOWOOD, Distribution, Unattended 2021-12-31 C008999 ferc:CurrentYearMember Compliance Deductionferc:SulfurDioxideMember 2021-01-012021-12-31 C008999 HORN LAKE, Transmission, Unattended 2021-12-31 C008999 LEXINGTON, Distribution, Unattended 2021-12-31 C008999 Receipts & Sales, Other State Tax, ,ferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 MPSC  - Docket No. 2009-UN-388 - Attorney General Litigation 2020-12-31 C008999 Asset Retirement Obligation - Coal 2021-12-31 C008999 2020-12-31 C008999 Gerald Andrus 314 2021-01-012021-12-31 C008999 Build Pine Tree 230/12.47kV Subferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 RANKIN, Transmission, Unattended 2021-12-31 C008999 MISO Rider Over-Recovery MPSC Docket No. 2014-UN-132 2021-12-31 C008999 RAY BRASWELL EHV, Transmission, Unattended 2021-01-012021-12-31 C008999 Asset Suite/AIMM Repl - Supply Chaiferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMemberferc:GeneralPlantMember 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember WINONA-SAWYER RD BIEWER LUMBER 2R04 2021-12-31 C008999 ferc:ElectricUtilityMember See Footnote 2021-12-31 C008999 Restructuring Credit Rider Under-Recovery MPSC Docket No. 2018-UA-39 2021-01-012021-12-31 C008999 2020 - Jackson North - Jackson Nort 2021-01-012021-12-31 C008999 JACKSON/WEST, Distribution, Unattended 2021-12-31 C008999 5% surcharge on regulated billings to non-regulated affiliates 2021-01-012021-12-31 C008999 ferc:OtherFederalTaxMember 2020-12-31 C008999 HER - New Desoto Service Centerferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 NEW HEBRON, Distribution, Unattended 2021-01-012021-12-31 C008999 ferc:AdValoremTaxMember 2021-01-012021-12-31 C008999 CLEVELAND/SOUTH, Distribution, Unattended 2021-12-31 C008999 10%ferc:ElectricUtilityMember 2021-12-31 C008999 Entergy Services, LLC, Other Allocated Tax, , 2021-12-31 C008999 ferc:ElectricUtilityMember Other distribution lines plant 2021-01-012021-12-31 C008999 Mobile device services 2021-01-012021-12-31 C008999 Changes in money pool receivable - net 2021-01-012021-12-31 C008999 Changes in money pool receivable - net 2020-01-012020-12-31 C008999 Hinds 2021-12-31 C008999 Independence Un 2 315 2021-01-012021-12-31 C008999 ROSEDALE [MS], Distribution, Unattended 2021-01-012021-12-31 C008999 Baxter Wilson Com 311 2021-01-012021-12-31 C008999 HORN LAKE, GETWELL 230KV LN 225 [6186], Single Concr, 1272 ACSR 2021-01-012021-12-31 C008999 JACKSON/NORTHWEST, Distribution, Unattended 2021-12-31 C008999 Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff, Docket No. ER18-1247 2021-01-012021-12-31 C008999 ferc:StateTaxMember 2021-12-31 C008999 ferc:AprilMember Entergy Mississippi, LLC 2021-01-012021-12-31 C008999 Qualified Pension funded status 2020-12-31 C008999 2021-12-31 C008999 SCHLATER, Distribution, Unattended 2021-12-31 C008999 ferc:ElectricUtilityMember HWY-2020-GM01-DF400-BOZEMAN RD OH 1 2021-01-012021-12-31 C008999 MPSC  - Docket No. 2009-UN-388 - Attorney General Litigation 2021-12-31 C008999 LUCKNEY, RANKIN 230KV LN 211 [6298], Steel Pole, 1272 ACSR 2021-01-012021-12-31 C008999 Deferred rebate 2021-12-31 C008999 RULEVILLE, Distribution, Unattended 2021-01-012021-12-31 C008999 JACKSON/EAST, Distribution, Unattended 2021-12-31 C008999 3.75% Series 2021-01-012021-12-31 C008999 2020 - MADISON - CANTON - 6C07 - QFferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 GMS -ERDC Back-up Generator 2021-01-012021-12-31 C008999 FLORENCE, Distribution, Unattended 2021-01-012021-12-31 C008999 Non-Expense Accrued Labor 2020-12-31 C008999 ferc:ElectricUtilityMemberferc:ElectricPlantInServiceMember 2021-01-012021-12-31 C008999 Restructuring Credit Rider Under-Recovery MPSC Docket No. 2018-UA-39 2020-12-31 C008999 Jackson, W: rpl RTUferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 Choctaw Unit 1 342 2021-01-012021-12-31 C008999 HARPER, Transmission, Unattended 2021-12-31 C008999 Highway 51 Warehouse Relocation 2021-01-012021-12-31 C008999 2020 Planning SE17-012A Regs/RC RREferc:ElectricUtilityMember 2021-12-31 C008999 Deferred COVID-19 costs MPSC Docket No. 2018-AD-141 - Amort July 2021-June 2022 2020-12-31 C008999 Independence Un 1 315 2021-01-012021-12-31 C008999 GGNS: E&D ST-21 Xfmr Bay Upgd 2021-01-012021-12-31 C008999 Pickens replace breaker J1708, lineferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 Gerald Pipelines 312 2021-01-012021-12-31 C008999 Contra UA 396_RES 2021-01-012021-12-31 C008999 LULA, Distribution, Unattended 2021-12-31 C008999 ROXIE, Distribution, Unattended 2021-12-31 C008999 Indianola: E&D J3110 Xfmr Bay Upgd 2021-01-012021-12-31 C008999 ATTALA, Transmission, Unattended 2021-01-012021-12-31 C008999 EML Public EV Charging Pilotferc:ElectricUtilityMember 2021-12-31 C008999 JACKSON/WATERWORKS, Distribution, Unattended 2021-01-012021-12-31 C008999 2020-Rankin-Henderson Rd-E Metro Pk 2021-01-012021-12-31 C008999 TILLATOBA, Transmission, Unattended 2021-12-31 C008999 LAKE CASTLE, Distribution, Unattended 2021-12-31 C008999 Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff, Docket No. ER15-358 2021-01-012021-12-31 C008999 General Plant 390.1 2021-01-012021-12-31 C008999 GREENVILLE/SOUTHEAST, Distribution, Unattended 2021-01-012021-12-31 C008999 VICKSBURG/EAST SS, Transmission, Unattended 2021-12-31 C008999 T&D 2021 Rankin UG  - N1 2021-01-012021-12-31 C008999 BYHALIA, Distribution, Unattended 2021-01-012021-12-31 C008999 Mississippi Power & Light Co. 2021-01-012021-12-31 C008999 Gallatin: rpl FX20 & add FX10 Fdr  2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember Yandell Sub Upgrades 2021-01-012021-12-31 C008999 FLI-SENATOBIA NETWORK-SENATOBIA-1H0ferc:ElectricUtilityMember 2021-12-31 C008999 ferc:ElectricUtilityMember Other general and intangible plant 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember Franklin: AT1 Cph/Spare Life Extend 2021-01-012021-12-31 C008999 Independence Un 1 314 2021-01-012021-12-31 C008999 ferc:FranchiseTaxMember 2020-12-31 C008999 C6PPTM2110: Brookhaven - Wesson 115 2021-01-012021-12-31 C008999 Restructuring Credit Rider Under-Recovery MPSC Docket No. 2018-UA-39 2021-12-31 C008999 Hinds Unit 2 346 2021-01-012021-12-31 C008999 KINGSWOOD/JACKSON, Distribution, Unattended 2021-12-31 C008999 Other transmission lines plantferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 ferc:Quarter2Member Entergy Mississippi, LLC 2021-01-012021-12-31 C008999 Contra UA 397.2_RES 2021-01-012021-12-31 C008999 LAKEOVER, LUCKNEY 230KV LN 211 [2311], Wood H-Frame, 1272 ACSR 2021-01-012021-12-31 C008999 Paul D. Hinnenkamp 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember T&D 2021 Rankin UG  - N1 2021-01-012021-12-31 C008999 ServiceNow Enhancementsferc:ElectricUtilityMember 2021-12-31 C008999 Grid Modernization Rider Over-Recovery MPSC Docket No. 2017-UN-198 2021-12-31 C008999 GREENVILLE/MIDTOWN, Distribution, Unattended 2021-12-31 C008999 Other distribution lines plant 2021-01-012021-12-31 C008999 HOY ROAD, Distribution, Unattended 2021-12-31 C008999 ferc:ElectricUtilityMember Relocate Facilities W Capitol St 2021-01-012021-12-31 C008999 2.85% Series 2021-01-012021-12-31 C008999 RFL-16 Rural Flood Lighting 2021-01-012021-12-31 C008999 Independence Un 2 311 2021-01-012021-12-31 C008999 DESOTO, Distribution, Unattended 2021-01-012021-12-31 C008999 GM-Guild 33-FA06-Rebuild-Cleary Rd 2021-01-012021-12-31 C008999 Build Pine Tree 230/12.47kV Sub 2021-01-012021-12-31 C008999 ELTON RD, Distribution, Unattended 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember 2021 - Midstate - Kosciusko - Insta 2021-01-012021-12-31 C008999 GM-Guild 33-GK01-Asset Op-Cap Bankferc:ElectricUtilityMember 2021-12-31 C008999 Delta Unit 2 315_RES 2021-01-012021-12-31 C008999 Allowances Usedferc:NitrogenOxideMember 2021-01-012021-12-31 C008999 Attala Unit 1 346 2021-01-012021-12-31 C008999 Qualified Pension Settlement Cost Deferral MPSC Docket No. 2020-UA-91 Amort 130 months beg Oct 2020 2021-12-31 C008999 MIDNIGHT, Distribution, Unattended 2021-12-31 C008999 Entergy Services, LLC, Income Tax, ,ferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 MOON LAKE SS, Transmission, Unattended 2021-12-31 C008999 MARKS, Distribution, Unattended 2021-01-012021-12-31 C008999 C-29 Large General Service 2021-01-012021-12-31 C008999 VICKSBURG/EAST SS, Transmission, Unattended 2021-01-012021-12-31 C008999 2021 - Cleveland - Belzoni - 4H01 -ferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 RAY BRASWELL, BWSES 500KV LN 502 [6880], Steel Tower, 954 ACSR 2021-01-012021-12-31 C008999 CRYSTAL SPRINGS, Distribution, Unattended 2021-12-31 C008999 BYHALIA, Distribution, Unattended 2021-12-31 C008999 WYNNDALE, Distribution, Unattended 2021-01-012021-12-31 C008999 Corporate Franchise Tax-AR, Franchise Tax, , 2021-12-31 C008999 MISO Rider Over-Recovery MPSC Docket No. 2014-UN-132 2021-01-012021-12-31 C008999 Choctaw 2021-12-31 C008999 ferc:ElectricUtilityMember T&D - Flora Add Transformer - West 2021-12-31 C008999 B(1), EPRI dues 2 2021-01-012021-12-31 C008999 Other Deductions (Account 4265) 2021-01-012021-12-31 C008999 Other transmission lines plantferc:ElectricUtilityMember 2021-12-31 C008999 MEDICAL CENTER/JACKSON, Distribution, Unattended 2021-12-31 C008999 CATLETT, Distribution, Unattended 2021-01-012021-12-31 C008999 Grid Modernization Rider Over-Recovery MPSC Docket No. 2017-UN-198 2021-01-012021-12-31 C008999 GREENVILLE, Distribution, Unattended 2021-01-012021-12-31 C008999 Transmission 350.2 2021-01-012021-12-31 C008999 GREENVILLE, Distribution, Unattended 2021-12-31 C008999 2021-Magee-Mendenhall-Relocate Faciferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 Independence Com 315 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember GM-Guild 33-GK01-Focus Rebuild-Fore 2021-01-012021-12-31 C008999 MP-22 Municipal Pumping Power Service 2021-01-012021-12-31 C008999 Mississippi Power & Light Co.ferc:SubsidiaryCompanySubheadingMember 2021-01-012021-12-31 C008999 ferc:OtherUseTaxMember 2020-12-31 C008999 2021 Planning CV20-002A New Build N 2021-01-012021-12-31 C008999 4.9% Series 2021-12-31 C008999 GGNS, FRANKLIN 500KV LN 506 [5640], Steel Tower, 954 ACSR 2021-01-012021-12-31 C008999 ferc:OtherTaxesAndFeesMember 2020-12-31 C008999 T&D - Flora Add Transformer - North 2021-01-012021-12-31 C008999 Rex Brown Unit 2 311_RES 2021-01-012021-12-31 C008999 ferc:Quarter3Member 0 2021-01-012021-12-31 C008999 Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff, Docket No. ER21-1997 2021-01-012021-12-31 C008999 Natchez Trace @ Hwy 43  UG Installa 2021-01-012021-12-31 C008999 Northpark: Add 230/115kV-400MVA Aut 2021-01-012021-12-31 C008999 2019-12-31 C008999 Pickens replace breaker J1708, lineferc:ElectricUtilityMember 2021-12-31 C008999 Entergy System Power Pool , OS, 94 2021-01-012021-12-31 C008999 FP# F1PPU27609-Brookhaven-West McCo 2021-01-012021-12-31 C008999 Privilege License, Other Taxes, , 2021-01-012021-12-31 C008999 ferc:FuelTaxMemberferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 Midcontinent ISO, Inc. , OS , 2021-01-012021-12-31 C008999 Hinds Unit 1 344 2021-01-012021-12-31 C008999 UTICA, Distribution, Unattended 2021-01-012021-12-31 C008999 Jackson, S: E&D J4674 Bay Upgrade 2021-01-012021-12-31 C008999 ferc:ExciseTaxMember 2021-12-31 C008999 ferc:MarchMember 0 2021-01-012021-12-31 C008999 2021 - Jackson Downtown UG Network 2021-01-012021-12-31 C008999 Other 2021-01-012021-12-31 C008999 LED-2 LED Street and Area  Lighting 2021-01-012021-12-31 C008999 Distribution 365.1 2021-01-012021-12-31 C008999 VICKSBURG/SOUTHEAST, Distribution, Unattended 2021-01-012021-12-31 C008999 Fannin Rd: add Fdr Bkr Amp Transducferc:ElectricUtilityMember 2021-12-31 C008999 Baxter Wilson Un 1 314 2021-01-012021-12-31 C008999 Baxter Wilson Com 315 2021-01-012021-12-31 C008999 ferc:SulfurDioxideMember 2020-12-31 C008999 GALLATIN STREET/JACKSON, Distribution, Unattended 2021-01-012021-12-31 C008999 BRICKYARD, Distribution, Unattended 2021-12-31 C008999 Independence Com 312.1 2021-01-012021-12-31 C008999 EML:115-4.16 | 12.5MVA | JTreatmentferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 Accumulated Miscellaneous Operating Provisions (Account 2284)ferc:DirectPayrollDistributionMember 2021-01-012021-12-31 C008999 MISO Sch 1 Sched/Sys Ctrl/Disp 2021-01-012021-06-30 C008999 ferc:ElectricUtilityMember See Footnote 2021-01-012021-12-31 C008999 Bowling Green - Durant 115kV CAPferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 SNOWDEN PARK DIST. ROW 2021-01-012021-12-31 C008999 3.1% Series 2021-12-31 C008999 MEADVILLE, Distribution, Unattended 2021-01-012021-12-31 C008999 MCCOMB/WEST, Distribution, Unattended 2021-12-31 C008999 GS-298 General Lighting and Power 2021-01-012021-12-31 C008999 Hinds Unit 1 345 2021-01-012021-12-31 C008999 Entergy Power & Light Company 2021-12-31 C008999 MIDWAY RD IMPROVEMENT PROJECT - CLIferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 GREENVILLE/INDUSTRIAL, Distribution, Unattended 2021-12-31 C008999 Other 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember SAISO Replacement 2021-12-31 C008999 ferc:TwoYearsMemberferc:SulfurDioxideMember 2021-01-012021-12-31 C008999 ferc:LocalTaxMember 2020-12-31 C008999 PELAHATCHIE, Distribution, Unattended 2021-01-012021-12-31 C008999 FREEPORT, TUNICA 230KV LN 213,238 [5525], Steel Tower, 1272 ACSR 2021-01-012021-12-31 C008999 CANTON, Distribution, Unattended 2021-01-012021-12-31 C008999 ferc:OperatingUtilityMember 2021-12-31 C008999 SUNNYBROOK, Distribution, Unattended 2021-01-012021-12-31 C008999 DSL-16 Directional Security  Lighting 2021-01-012021-12-31 C008999 ferc:NextTwelveMonthsMemberferc:SulfurDioxideMember 2021-12-31 C008999 ferc:OtherStateTaxMember 2020-12-31 C008999 0, 0 2021-01-012021-12-31 C008999 GRENADA/SOUTH, Transmission, Unattended 2021-12-31 C008999 ROBINSONVILLE, Distribution, Unattended 2021-12-31 C008999 ScheduleStatementOfAccumulatedOtherComprehensiveIncomeAndHedgingActivitiesAbstract 2021-01-012021-12-31 C008999 Rex Brown Common 316 2021-01-012021-12-31 C008999 Contra UA 394_RES 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember BWSES: J2200 AT1 Spare Life Extend 2021-01-012021-12-31 C008999 LIVINGSTON ROAD/JACKSON, Distribution, Unattended 2021-12-31 C008999 ferc:LocalTaxMember 2021-12-31 C008999 DESOTO, Distribution, Unattended 2021-12-31 C008999 ferc:ElectricUtilityMember GM-Guild 33-GK01-Focus Rebuild-Fore 2021-12-31 C008999 Franklin 500kV Reconfigurationferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 MPSC - Docket No. 2010-AD-2 - MS EE Comprehensive Portfolio Program 2021-01-012021-12-31 C008999 YAZOO CITY SS, Distribution, Unattended 2021-12-31 C008999 ferc:MiscellaneousOtherTaxMember 2020-12-31 C008999 MISO Sch 2 Reactive 2021-01-012021-12-31 C008999 Other 2020-01-012020-12-31 C008999 Federal Income Tax, Federal Tax, , 2020-12-31 C008999 ferc:ElectricUtilityMember 3% 2021-01-012021-12-31 C008999 FLOWOOD, Distribution, Unattended 2021-01-012021-12-31 C008999 INDIANOLA 230/115 SUB, Transmission, Unattended 2021-12-31 C008999 Rankin 115kV Sub - Add Line Bay 2021-01-012021-12-31 C008999 SOUTH CANTON, RAGSDALE 230KV LN 223 & 224 [5271], Single Concr, 1272 ACSR 2021-01-012021-12-31 C008999 Deferred Attorney General Litigation Costs MPSC Docket No. 2009-UN-388 Amort 6 years beg April 2020 2021-12-31 C008999 ferc:ElectricUtilityMember DeSoto County-Ross Meadows Land-M&R 2021-01-012021-12-31 C008999 NORTHSIDE DRIVE/JACKSON, Distribution, Unattended 2021-12-31 C008999 JACKSON/WEST, Distribution, Unattended 2021-01-012021-12-31 C008999 FP# F1PPU27609-FLI-Brookhaven-Westferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 Privilege License, Other Taxes, , 2021-12-31 C008999 ferc:ElectricUtilityMember Greenville TCEPA - Arcola 115kV CAP 2021-12-31 C008999 LIBERTY, Distribution, Unattended 2021-12-31 C008999 Mississippi Power & Light Co.ferc:UnappriatedUndistributedSubsidiaryEarningsMember 2020-12-31 C008999 STRINGTOWN, Distribution, Unattended 2021-01-012021-12-31 C008999 Delta Common 311 2021-01-012021-12-31 C008999 3.85% Series 1 2021-12-31 C008999 UFL-16 Urban Flood Lighting 2021-01-012021-12-31 C008999 WYNNDALE, Distribution, Unattended 2021-12-31 C008999 VICKSBURG/SOUTH, Distribution, Unattended 2021-01-012021-12-31 C008999 DeSoto County-Ross Meadows Land-M&R 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember 2021 RANKIN MORTON 6R02 55Q0022 2021-01-012021-12-31 C008999 ferc:PropertyTaxMember 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMemberferc:OtherLicenseAndFeesTaxMember 2021-01-012021-12-31 C008999 ferc:CurrentYearMemberferc:NitrogenOxideMember 2020-12-31 C008999 Employment Litigation 2021-01-012021-12-31 C008999 TINNIN RD, NORRELL 230KV LN 239 [2339], Steel Pole, 1272 ACSR 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember WINONA-SAWYER RD BIEWER LUMBER 2R04 2021-01-012021-12-31 C008999 General Plant 396 2021-01-012021-12-31 C008999 CENTREVILLE, Distribution, Unattended 2021-01-012021-12-31 C008999 MIAMI STREET/JACKSON, Distribution, Unattended 2021-12-31 C008999 3.75% Series 2021-12-31 C008999 MEDICAL CENTER/JACKSON, Distribution, Unattended 2021-01-012021-12-31 C008999 ferc:OtherPropertyTaxMember 2021-12-31 C008999 Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff, Docket No. ER19-1503 2021-01-012021-12-31 C008999 GREENVILLE/INDUSTRIAL, Distribution, Unattended 2021-01-012021-12-31 C008999 Increases (Decreases) from Gain or Resale or Cancellation of Reacquired Capital Stock 2021-01-012021-12-31 C008999 MPSC - Docket No. 2010-AD-2 - MS EE Comprehensive Portfolio Program 2021-12-31 C008999 ferc:SalesAndUseTaxMember 2021-01-012021-12-31 C008999 Other 2021-01-012021-12-31 C008999 Choctaw Unit 1 343 2021-01-012021-12-31 C008999 2020 - RANKIN - AIRPORT - 6A04 - 55 2021-01-012021-12-31 C008999 CANTON ROAD/JACKSON, Distribution, Unattended 2021-01-012021-12-31 C008999 Independence Un 1 316 2021-01-012021-12-31 C008999 MONUMENT STREET/JACKSON, Distribution, Unattended 2021-12-31 C008999 GREENVILLE/EAST, Distribution, Unattended 2021-12-31 C008999 Formula Rate Plan Revenue Increase MPSC Docket No. 2018-UN-205 2021-12-31 C008999 WINONA, Distribution, Unattended 2021-01-012021-12-31 C008999 Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Baseline Tariff, Docket No. ER13-1508 2021-01-012021-12-31 C008999 Utility Data Warehouse Plus 2021-01-012021-12-31 C008999 MISO Sch 2 Reactive 2021-01-012021-03-31 C008999 Northpark: Add 230/115kV-400MVA Autferc:ElectricUtilityMember 2021-12-31 C008999 VICKSBURG/SOUTH, Distribution, Unattended 2021-12-31 C008999 Mississippi Power & Light Co. 2021-12-31 C008999 ferc:OtherUtilityOrNonutilityMember 2021-01-012021-12-31 C008999 Electric Deferred Fuel Over-Recovery 2020-12-31 C008999 Choctaw Unit 1 345 2021-01-012021-12-31 C008999 Current Period Adjustmentferc:NitrogenOxideMember 2021-01-012021-12-31 C008999 Rex Brown Unit 2 314_RES 2021-01-012021-12-31 C008999 GETWELL, Distribution, Unattended 2021-01-012021-12-31 C008999 CHOCTAW, WOLF CREEK 500KV LN 515 [5015], Steel Pole, 954 ACSR 2021-01-012021-12-31 C008999 JACKSON/SOUTHWEST, Distribution, Unattended 2021-12-31 C008999 ferc:ElectricUtilityMember 2020 - Madison-Yandell-GY01 & GY05- 2021-01-012021-12-31 C008999 2020 Planning CL20-005V Rep A1, RRE 2021-01-012021-12-31 C008999 BAXTER WILSON SES SWYD, Transmission, Unattended 2021-12-31 C008999 INDIANOLA, TILLATOBA 230KV LN 207 [6020], Steel Tower, 1272 ACSR 2021-01-012021-12-31 C008999 ferc:SeveranceTaxMember 2020-12-31 C008999 ferc:NitrogenOxideMember 2021-01-012021-12-31 C008999 REX BROWN 230 SWYD, Transmission, Unattended 2021-01-012021-12-31 C008999 MISO Rider Over-Recovery MPSC Docket No. 2014-UN-132 2020-12-31 C008999 ISES Acquisition Adjustment 2020-12-31 C008999 Hinds Unit 2 342 2021-01-012021-12-31 C008999 LEXINGTON, Distribution, Unattended 2021-01-012021-12-31 C008999 LED-2 LED Street and Area  Lighting 2021-01-012021-12-31 C008999 WINONA-SAWYER RD-BIEWER LUMBER-EXTE 2021-01-012021-12-31 C008999 FICA, Federal Tax, ,ferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 ferc:OtherAllocatedTaxMember 2021-12-31 C008999 JACKSON/SOUTHWEST, Distribution, Unattended 2021-01-012021-12-31 C008999 ferc:TransmissionPlantMemberferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 Franchise - City, Local Tax, , 2021-01-012021-12-31 C008999 General Plant 397.1 2021-01-012021-12-31 C008999 NATCHEZ/INDUSTRIAL PARK, Distribution, Unattended 2021-01-012021-12-31 C008999 Clearing Accounts (Account 184) 2021-01-012021-12-31 C008999 The Light, Heat and Water Company of Jackson, Mississippi 2021-01-012021-12-31 C008999 FLOWERS, Distribution, Unattended 2021-12-31 C008999 WOLF CREEK, Transmission, Unattended 2021-12-31 C008999 Ad Valorem Tax - AR, Other Ad Valorem Tax, , 2020-12-31 C008999 Franklin-GGNS 500Kv Phase Swaferc:ElectricUtilityMember 2021-12-31 C008999 State Income Tax, State Tax, , 2021-01-012021-12-31 C008999 HORN LAKE, Distribution, Unattended 2021-01-012021-12-31 C008999 2020 Planning CL20-005V Rep A1, RREferc:ElectricUtilityMember 2021-12-31 C008999 Hinds 2021-01-012021-12-31 C008999 Hinds Unit 1 341 2021-01-012021-12-31 C008999 Rex Brown Unit 2 315_RES 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember EML: 115-13.8 | 20MVA (Marvell) 2021-01-012021-12-31 C008999 BATESVILLE, MOON LAKE 230KV LN 201 [6300], Steel Tower, 1272 ACSR 2021-01-012021-12-31 C008999 All 500 kV Lines, , , 2021-01-012021-12-31 C008999 3.5% Series 1 2021-12-31 C008999 See Footnote Detailferc:ElectricUtilityMember 2021-12-31 C008999 10% 2021-01-012021-12-31 C008999 MCADAMS, INDIANOLA 230KV LN 215 [6410], Wood H-Frame, 1272 ACSR 2021-01-012021-12-31 C008999 Qualified Pension funded status 2021-01-012021-12-31 C008999 AIRPORT/JACKSON, Distribution, Unattended 2021-12-31 C008999 JACKSON/TREATMENT PLANT, Distribution, Unattended 2021-01-012021-12-31 C008999 MCADAMS EHV, Transmission, Unattended 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember Other Debit or Cr. Items (Describe, details in footnote): 2021-01-012021-12-31 C008999 TF-23 Traffic Control Signals 2021-01-012021-12-31 C008999 BROOKHAVEN/SOUTH, Distribution, Unattended 2021-01-012021-12-31 C008999 CRENSHAW, Distribution, Unattended 2021-12-31 C008999 MISO Sch 1 Sched/Sys Ctrl/Disp 2021-01-012021-09-30 C008999 JACKSON/SOUTH, Transmission, Unattended 2021-01-012021-12-31 C008999 GETWELL, Transmission, Unattended 2021-12-31 C008999 CATLETT, TINNIN RD 230KV LN 234 [5112], Steel Pole, 1272 ACSR 2021-01-012021-12-31 C008999 GEORGETOWN [MS], Distribution, Unattended 2021-01-012021-12-31 C008999 ferc:OtherAdValoremTaxMember 2020-12-31 C008999 FANNIN ROAD, Distribution, Unattended 2021-12-31 C008999 DREW [MS], Distribution, Unattended 2021-01-012021-12-31 C008999 Johns-Manville: E&D J0467 Bay Upgd 2021-01-012021-12-31 C008999 2020 Planning CL20-005V Rep A1, RREferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 JACKSON/NORTHEAST, Distribution, Unattended 2021-01-012021-12-31 C008999 FREEPORT, Transmission, Unattended 2021-01-012021-12-31 C008999 TERRY, Distribution, Unattended 2021-12-31 C008999 ferc:MayMember 0 2021-01-012021-12-31 C008999 ferc:FebruaryMember Entergy Mississippi, LLC 2021-01-012021-12-31 C008999 Greenwood-Itta Bena 115Kv Cut-In 2021-01-012021-12-31 C008999 Non Income Tax, Miscellaneous Other Tax, , 2021-01-012021-12-31 C008999 IPS-26 Irrigation Pumping Power 2021-01-012021-12-31 C008999 Civil, Political, and Related Expenses (Account 4264) 2021-01-012021-12-31 C008999 NESBIT, Distribution, Unattended 2021-12-31 C008999 ferc:ElectricUtilityMember 2021 - Jackson Downtown UG Network 2021-01-012021-12-31 C008999 SW2 - EDE-Bill Syst Contr Repo Inteferc:ElectricUtilityMember 2021-12-31 C008999 MPSC  - Docket No. 2008-UN-381 - Power Management Rider Expense 2021-01-012021-12-31 C008999 SOUTH JACKSON, RANKIN 230 KV LN 233 [7350], Steel Pole, 1272 ACSR 2021-01-012021-12-31 C008999 EMI New Nuclear, LLCferc:UnappriatedUndistributedSubsidiaryEarningsMember 2021-12-31 C008999 RAY BRASWELL, WEST POINT 500KV LN 508 [6960], Steel Tower, 954 ACSR 2021-01-012021-12-31 C008999 Distribution 373.2 2021-01-012021-12-31 C008999 Defined Benefit Pension & Other Post Retirement Plans 2020-12-31 C008999 MINTER CITY SS, Transmission, Unattended 2021-01-012021-12-31 C008999 General Plant 391.1 2021-01-012021-12-31 C008999 Pelahatchie - Rankin 115kV CAPferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 WINONA-SAWYER RD BIEWER LUMBER 2R04 2021-01-012021-12-31 C008999 ferc:SteamProductionPlantMemberferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 ScheduleGeneratingPlantStatisticsAbstract 2021-01-012021-12-31 C008999 ferc:FederalInsuranceTaxMember 2021-12-31 C008999 HLF-7 High Load Factor 2021-01-012021-12-31 C008999 RANKIN, Distribution, Unattended 2021-12-31 C008999 Deferred Electric Storm Restoration Costs 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember Brookhaven Upgrade Transformer 2021-12-31 C008999 RANKIN, Distribution, Unattended 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember A1A - GE LTSA Budget Cap 2020-2024 2021-12-31 C008999 GM-39-3E08-C4 Capacitor Install Reeferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 SHELBY, Distribution, Unattended 2021-01-012021-12-31 C008999 BOLTON, Distribution, Unattended 2021-12-31 C008999 SPO EML SunflowerTaxEquityPartneshp 2021-01-012021-12-31 C008999 Choctaw Unit 1 346 2021-01-012021-12-31 C008999 JACKSON/SOUTH, Transmission, Unattended 2021-12-31 C008999 NATCHEZ/SOUTH, Distribution, Unattended 2021-12-31 C008999 ATTALA, Distribution, Unattended 2021-01-012021-12-31 C008999 Indianola: E&D J3110 Xfmr Bay Upgdferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 TILLATOBA, Transmission, Unattended 2021-01-012021-12-31 C008999 KOSCIUSKO, Distribution, Unattended 2021-01-012021-12-31 C008999 SPO EML SunflowerTaxEquityPartneshpferc:ElectricUtilityMember 2021-12-31 C008999 Hollandale: E&D 3J22 & 02 Bkr Rplferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 ferc:TwoYearsMemberferc:SulfurDioxideMember 2021-12-31 C008999 GLP-17 Gen. Lghtg. & Pwr Redist. & Res. 2021-01-012021-12-31 C008999 Deferred Payroll Employer Tax 2020-12-31 C008999 MPSC  - Docket No. 2018-UN-205 - EML Formula Rate Plan 2021-01-012021-12-31 C008999 EMI New Nuclear, LLCferc:SubsidiaryCompanySubheadingMember 2021-01-012021-12-31 C008999 Federal Uemployment Tax, Federal Tax, ,ferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 T&D - Flora Add Transformer - Northferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 ferc:FederalTaxMember 2020-12-31 C008999 ferc:OtherStateTaxMemberferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 HARPER, Transmission, Unattended 2021-01-012021-12-31 C008999 Greenwood-Itta Bena 115Kv Cut-Inferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 Energy Efficiency Rider Under-Recovery 2021-01-012021-12-31 C008999 Receipts & Sales, Other State Tax, , 2021-01-012021-12-31 C008999 Deferred Payroll Employer Tax 2021-01-012021-12-31 C008999 0, 0 2021-01-012021-12-31 C008999 Federal Excise Tax, Federal Tax, , 2021-01-012021-12-31 C008999 MADISON, Distribution, Unattended 2021-12-31 C008999 ROBINSON ROAD/JACKSON, Distribution, Unattended 2021-12-31 C008999 Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff, Docket No. ER17-1777 2021-01-012021-12-31 C008999 COLDWATER, Distribution, Unattended 2021-12-31 C008999 ferc:OctoberMember 0 2021-01-012021-12-31 C008999 Unit Power Cost Recovery Rider Over-Recovery MPSC Docket No. 2014-UN-132 2020-12-31 C008999 3.5% Series 2 2021-01-012021-12-31 C008999 Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff, Docket No. ER15-1436 2021-01-012021-12-31 C008999 Entergy Mississippi, LLCferc:JulyMember 2021-01-012021-12-31 C008999 ferc:SulfurDioxideMember 2021-12-31 C008999 MORTON, Distribution, Unattended 2021-01-012021-12-31 C008999 SENATOBIA, Distribution, Unattended 2021-01-012021-12-31 C008999 MPSC  - Docket No. 2017-UA-189 - MISO Renewal Cost Benefit Analysis 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember Greenville TCEPA - Arcola 115kV CAP 2021-01-012021-12-31 C008999 ferc:ElectricOtherFacilitiesMember Other (provide details in footnote): 2021-01-012021-12-31 C008999 HENDERSON ROAD, Distribution, Unattended 2021-12-31 C008999 Corporate Franchise Tax-AR, Franchise Tax, , 2020-12-31 C008999 CHOCTAW, FRENCH CAMP 500KV LN 514 [5014], Steel Pole, 954 ACSR 2021-01-012021-12-31 C008999 WHITFIELD, Distribution, Unattended 2021-01-012021-12-31 C008999 LARSON ST/JACKSON, Distribution, Unattended 2021-12-31 C008999 Delta Unit 1 312_RES 2021-01-012021-12-31 C008999 Delta Unit 1 315_RES 2021-01-012021-12-31 C008999 EMI New Nuclear, LLC 2021-12-31 C008999 Crenshaw: Add Circuit Switcherferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 CSD Workforce Management Systemferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 JONESTOWN, Distribution, Unattended 2021-01-012021-12-31 C008999 ferc:NextTwelveMonthsMemberferc:NitrogenOxideMember 2021-01-012021-12-31 C008999 2020 Planning CL20-005V New Build Nferc:ElectricUtilityMember 2021-12-31 C008999 SW2 - EDE-Bill Syst Contr Repo Inte 2021-01-012021-12-31 C008999 MOON LAKE, RITCHIE (MS/AR ST LN) 230KV LN 228 (OPCO TIE) [6320], Steel Tower, 1272 ACSR 2021-01-012021-12-31 C008999 ferc:IncomeTaxMember 2021-12-31 C008999 ALGS-10 Alternate Large General Service 2021-01-012021-12-31 C008999 2022-Vicksburg-Glass Road 2021-01-012021-12-31 C008999 GM-Guild 33-GK01-Asset Op-Cap Bankferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 Other expenses incurred in connection with MISO and other transmission related FERC dockets 2021-01-012021-12-31 C008999 Deposit Alternative Payferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 CANTON ROAD/JACKSON, Distribution, Unattended 2021-12-31 C008999 Franklin 500kV Reconfiguration 2021-01-012021-12-31 C008999 EMI New Nuclear, LLCferc:UnappriatedUndistributedSubsidiaryEarningsMember 2020-12-31 C008999 GREENVILLE/EAST, Distribution, Unattended 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 State Income Tax, State Tax, ,ferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 LUCKNEY, Distribution, Unattended 2021-12-31 C008999 Choctaw Unit 1 344 2021-01-012021-12-31 C008999 Brookhaven Upgrade Transformer 2021-01-012021-12-31 C008999 State Use Tax, Sales And Use Tax, , 2021-01-012021-12-31 C008999 MCADAMS, PICKENS 230KV LN 209 [6416], Wood H-Frame, 1272 ACSR 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMemberferc:FederalInsuranceTaxMember 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember Nesbit-Laughter Road-Bridgforth Pro 2021-12-31 C008999 Downtown Jackson - Replace 1500 KVA 2021-01-012021-12-31 C008999 JACKSON/EAST, Distribution, Unattended 2021-01-012021-12-31 C008999 Income Taxes 2021-01-012021-12-31 C008999 RS-38W Residential Water Heating Service 2021-01-012021-12-31 C008999 ferc:OtherUtilityOrNonutilityMember 0 2021-01-012021-12-31 C008999 Contra UA 391.2_RES 2021-01-012021-12-31 C008999 WHITFIELD, Distribution, Unattended 2021-12-31 C008999 SW2 - EDE-Bill Syst Contr Repo Inteferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 Clinton Ind: rpl Ckt Sw & Upgd Bayferc:ElectricUtilityMember 2021-12-31 C008999 Choctaw Unit 1 340.1 2021-01-012021-12-31 C008999 ferc:GasOtherFacilitiesMember Other (provide details in footnote): 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember Whitfield: add Ckt Sw, rpl T1 Diff 2021-12-31 C008999 E. Vicksburg-E. Vicksburg 115kV CAP 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMemberferc:IncomeTaxMember 2021-01-012021-12-31 C008999 ferc:SulfurDioxideMemberferc:ThreeYearsMember 2021-01-012021-12-31 C008999 Non-Qualified Pension funded status 2021-01-012021-12-31 C008999 Hinds Unit 2 345 2021-01-012021-12-31 C008999 Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff, Docket No. ER20-1472 2021-01-012021-12-31 C008999 MIAMI STREET/JACKSON, Distribution, Unattended 2021-01-012021-12-31 C008999 WEBB, Distribution, Unattended 2021-12-31 C008999 Contra UA 395_RES 2021-01-012021-12-31 C008999 MORTON, Distribution, Unattended 2021-12-31 C008999 FAYETTE, Distribution, Unattended 2021-12-31 C008999 BOZEMAN ROAD, Distribution, Unattended 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember 2021 - Jackson Downtown UG Network 2021-12-31 C008999 2021 FOCUS FC21M021 Natchez 8F05 Ro 2021-01-012021-12-31 C008999 GM-Vicksburg SE Guild 5F03-N6, FSW1ferc:ElectricUtilityMember 2021-12-31 C008999 E. Vicksburg-E. Vicksburg 115kV CAPferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 Natchez Trace @ Hwy 43  UG Installaferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 HER - New Desoto Service Centerferc:ElectricUtilityMember 2021-12-31 C008999 2020-Madison-Hoy Rd-Natchez Trace @ 2021-01-012021-12-31 C008999 ferc:AfterThreeYearsMemberferc:SulfurDioxideMember 2021-01-012021-12-31 C008999 Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff, Docket No. ER17-2579 2021-01-012021-12-31 C008999 MIDWAY RD IMPROVEMENT PROJECT - CLIferc:ElectricUtilityMember 2021-12-31 C008999 CENTREVILLE, Distribution, Unattended 2021-12-31 C008999 ferc:SulfurDioxideMemberferc:ThreeYearsMember 2021-12-31 C008999 Independence Com 311 2021-01-012021-12-31 C008999 2020 Planning CL20-005V New Build Nferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 ferc:DirectPayrollDistributionMember Clearing Accounts (Account 184) 2021-01-012021-12-31 C008999 ELTON RD, Distribution, Unattended 2021-12-31 C008999 Distribution 371 2021-01-012021-12-31 C008999 Whitfield: add Ckt Sw, rpl T1 Diff 2021-01-012021-12-31 C008999 STRINGTOWN, Distribution, Unattended 2021-12-31 C008999 TINNIN ROAD, Distribution, Unattended 2021-12-31 C008999 ferc:ElectricUtilityMember 2021 SHN JXSNSW-KINGSW - 2 RCs 2021-12-31 C008999 GMS -ERDC Back-up Generatorferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 ferc:NextTwelveMonthsMemberferc:NitrogenOxideMember 2021-12-31 C008999 See Footnote Detailferc:ElectricUtilityMember 2020-12-31 C008999 Purchases/Transfers:ferc:SulfurDioxideMember 2021-01-012021-12-31 C008999 Hinds Unit 2 341 2021-01-012021-12-31 C008999 GLEN ALLAN, Distribution, Unattended 2021-12-31 C008999 ferc:ElectricUtilityMember State Unemployment Tax, Unemployment Tax, , 2021-01-012021-12-31 C008999 CANTON, PICKENS 230KV LN 230 [5270], Single Concr, 1272 ACSR 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember SNOWDEN PARK DIST. ROW 2021-01-012021-12-31 C008999 Accumulated Provisions for Property Insurance (Account 2281) 2021-01-012021-12-31 C008999 Gerald Andrus 2021-01-012021-12-31 C008999 ferc:FuelTaxMember 2020-12-31 C008999 ferc:ElectricUtilityMember HWY-2020-GM01-DF400-BOZEMAN RD OH 1 2021-12-31 C008999 Winona-623 SAWYER RD EXT WINONA,MS-ferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 General Plant 397.2 2021-01-012021-12-31 C008999 LELAND, Distribution, Unattended 2021-01-012021-12-31 C008999 BROOKHAVEN, Distribution, Unattended 2021-01-012021-12-31 C008999 ferc:PropertyTaxMember 2020-12-31 C008999 B(4), Transmission University Research 2021-01-012021-12-31 C008999 CLEVELAND [MS], Distribution, Unattended 2021-12-31 C008999 BRICKYARD, Distribution, Unattended 2021-01-012021-12-31 C008999 Delta Common 316_RES 2021-01-012021-12-31 C008999 Clinton - Phase 1 / District 6-City 2021-01-012021-12-31 C008999 ROBINSONVILLE, Distribution, Unattended 2021-01-012021-12-31 C008999 TINNIN ROAD, Distribution, Unattended 2021-01-012021-12-31 C008999 ferc:MiscellaneousOtherTaxMember 2021-12-31 C008999 PAL-17 Private Area Lighting 2021-01-012021-12-31 C008999 B-34 Intermediate General Service 2021-01-012021-12-31 C008999 Transmission 357 2021-01-012021-12-31 C008999 Attala Gas 2021-01-012021-12-31 C008999 Natchez Trace @ Hwy 43  UG Installaferc:ElectricUtilityMember 2021-12-31 C008999 HORN LAKE, Transmission, Unattended 2021-01-012021-12-31 C008999 , , 2021-01-012021-12-31 C008999 T&D - Catlett 230kv Sub - Substatioferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 MPSC  - Docket No. 2017-UA-189 - MISO Renewal Cost Benefit Analysis 2021-12-31 C008999 Digital LIHEAPferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 Midcontinent ISO, Inc., OS, 2021-01-012021-12-31 C008999 Deferred COVID-19 costs MPSC Docket No. 2018-AD-141 - Amort July 2021-June 2022 2021-01-012021-12-31 C008999 Power Management Rider Over-Recovery MPSC Docket 2021-01-012021-12-31 C008999 2021 - Midstate - Kosciusko - Insta 2021-01-012021-12-31 C008999 MILL STREET, Distribution, Unattended 2021-01-012021-12-31 C008999 Clinton Ind: rpl Ckt Sw & Upgd Bay 2021-01-012021-12-31 C008999 PLUM POINT, Distribution, Unattended 2021-12-31 C008999 Attala Common 345 2021-01-012021-12-31 C008999 VICKSBURG/WEST, Distribution, Unattended 2021-12-31 C008999 ferc:OtherFederalTaxMember 2021-12-31 C008999 ferc:OperatingUtilityMember 2021-01-012021-12-31 C008999 2020-SuccessAudit-SA20M011-Southave 2021-01-012021-12-31 C008999 GALLATIN STREET/JACKSON, Distribution, Unattended 2021-12-31 C008999 Payment for Purchase of Assets 2020-01-012020-12-31 C008999 Mississippi Power & Light Co.ferc:UnappriatedUndistributedSubsidiaryEarningsMember 2021-12-31 C008999 Other Accounts (Specify, details in footnote):ferc:ElectricUtilityMemberferc:ElectricPlantInServiceMember 2021-01-012021-12-31 C008999 ferc:OtherTaxesAndFeesMember 2021-12-31 C008999 ferc:CapitalContributionMember EMI New Nuclear, LLC 2021-12-31 C008999 GM-Vicksburg SE Guild 5F03-N6, FSW1 2021-01-012021-12-31 C008999 GRAND GULF TRANSMISSION, Transmission, Unattended 2021-01-012021-12-31 C008999 GM-Vicksburg SE Guild 5F03-N6, FSW1ferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember HN1 - Hinds LTSA Capital 2021-12-31 C008999 Increases (Decreases) Due to Reductions in Par or Stated Value of Capital Stock 2021-01-012021-12-31 C008999 Ad Valorem Tax - AR, Other Ad Valorem Tax, , 2021-01-012021-12-31 C008999 HENDERSON ROAD, Distribution, Unattended 2021-01-012021-12-31 C008999 Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff, Docket No. ER22-489 2021-01-012021-12-31 C008999 3.25% Series 2021-12-31 C008999 ScheduleUnrecoveredPlantAndRegulatoryStudyCostsAbstract 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember Clinton - Phase 1 / District 6-City 2021-01-012021-12-31 C008999 Non-Expense Accrued Labor 2021-01-012021-12-31 C008999 ELLIOTT SS, Transmission, Unattended 2021-12-31 C008999 Other Accounts (Specify, details in footnote):ferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 LULA, Distribution, Unattended 2021-01-012021-12-31 C008999 ferc:DirectPayrollDistributionMember Accumulated Provisions for Property Insurance (Account 2281) 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember Rankin 115kV Sub - Add Line Bay 2021-01-012021-12-31 C008999 TWINKLETOWN, Distribution, Unattended 2021-12-31 C008999 Attala Common 343 2021-01-012021-12-31 C008999 B(1), EPRI dues 1 2021-01-012021-12-31 C008999 Other 2021-01-012021-12-31 C008999 FP# F1PPU27609-FLI-Brookhaven-West 2021-01-012021-12-31 C008999 Greenbrook to Snowden Park 115kv Lnferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 BAXTER WILSON SES SWYD, Transmission, Unattended 2021-01-012021-12-31 C008999 Mississippi Power & Light Co.ferc:CapitalContributionMember 2020-12-31 C008999 Privilege License, Other Taxes, , 2020-12-31 C008999 Rex Brown Unit 2 312_RES 2021-01-012021-12-31 C008999 Attala Common 342 2021-01-012021-12-31 C008999 RS-38C Residential Service 2021-01-012021-12-31 C008999 ferc:OperatingUtilityMember 2020-12-31 C008999 2020 Planning SH20-005V Getwell - E 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember 2020 Focus 6R02 FC20M051 Rankin Rou 2021-01-012021-12-31 C008999 SL-37 Municipal Street Lighting 2021-01-012021-12-31 C008999 General Plant 394 2021-01-012021-12-31 C008999 Common equity distributions 2021-01-012021-12-31 C008999 SchedulePumpedStorageGeneratingPlantStatisticsAbstract 2021-01-012021-12-31 C008999 Mississippi Power & Light Co.ferc:UnappriatedUndistributedSubsidiaryEarningsMember 2021-01-012021-12-31 C008999 4% 2021-01-012021-12-31 C008999 Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff, Docket No. ER21-200 2021-01-012021-12-31 C008999 Independence 2021-01-012021-12-31 C008999 ferc:IntangiblePlantMemberferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 HORN LAKE, Distribution, Unattended 2021-12-31 C008999 Gerald Andrus 310.2 2021-01-012021-12-31 C008999 GETWELL, Transmission, Unattended 2021-01-012021-12-31 C008999 Natchez 311_RES 2021-01-012021-12-31 C008999 ferc:OtherLicenseAndFeesTaxMember 2020-12-31 C008999 SE-29 State Institutions 2021-01-012021-12-31 C008999 Independence Com 312 2021-01-012021-12-31 C008999 ferc:UnemploymentTaxMember 2021-12-31 C008999 2021 - Cleveland - Belzoni - 4H01 - 2021-01-012021-12-31 C008999 ferc:Quarter4Member Entergy Mississippi, LLC 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember Snowden Park-Bld 115kV Sub-Scoping 2021-01-012021-12-31 C008999 See Footnote Detail 2021-01-012021-12-31 C008999 Corporate purchasing card rebates 2021-01-012021-12-31 C008999 ferc:PenaltyTaxMember 2020-12-31 C008999 JACKSON/SOUTH, Distribution, Unattended 2021-12-31 C008999 EMI New Nuclear, LLCferc:UnappriatedUndistributedSubsidiaryEarningsMember 2021-01-012021-12-31 C008999 4.9% Series 2021-01-012021-12-31 C008999 ferc:OtherUseTaxMember 2021-12-31 C008999 GS-298 MS Gen. Lghtg & Pwr Muni. Service 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember Raleigh 115kV Sub - Add 2nd Transf 2021-01-012021-12-31 C008999 2021-01-012021-12-31 C008999 TYLERTOWN, Distribution, Unattended 2021-01-012021-12-31 C008999 Dividends on common equity 2020-01-012020-12-31 C008999 Jackson Gas Light Company 2021-12-31 C008999 Ad Valorem Tax Adjustment Rider MPSC Docket No. 2014-UN-132 2021-01-012021-12-31 C008999 Stores Expense Undistributed (Account 163) 2021-01-012021-12-31 C008999 COLDWATER, Distribution, Unattended 2021-01-012021-12-31 C008999 GS-298 General Lighting and Power 2021-01-012021-12-31 C008999 GMS -ERDC Back-up Generatorferc:ElectricUtilityMember 2021-12-31 C008999 Rankin -- Permanent Svc to Communitferc:ElectricUtilityMember 2021-12-31 C008999 Regulatory Commission, Other Taxes, , 2021-12-31 C008999 General Plant 390 2021-01-012021-12-31 C008999 Rankin -- Permanent Svc to Communit 2021-01-012021-12-31 C008999 ferc:MayMember Entergy Mississippi, LLC 2021-01-012021-12-31 C008999 10%ferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 ferc:DirectPayrollDistributionMember 2021-01-012021-12-31 C008999 GGNS: E&D ST-21 Xfmr Bay Upgdferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 EMI 2021 Dec Storm ferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 ScheduleMonthlyIsoOrRtoTransmissionSystemPeakLoadAbstract 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember Madison-Hwy 43-Expedition Point Dev 2021-12-31 C008999 ScheduleAccumulatedDeferredIncomeTaxesAcceleratedAmortizationPropertyAbstract 2021-01-012021-12-31 C008999 Hinds Unit 1 346 2021-01-012021-12-31 C008999 Power Generation Fleet Training Plaferc:ElectricUtilityMember 2021-12-31 C008999 ferc:OtherAllocatedTaxMemberferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 TUNICA, Distribution, Unattended 2021-01-012021-12-31 C008999 HLF-7 High Load Factor 2021-01-012021-12-31 C008999 Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff, Docket No. ER17-1549 2021-01-012021-12-31 C008999 Rex Brown Unit 2 316_RES 2021-01-012021-12-31 C008999 GRENADA/SOUTH, Transmission, Unattended 2021-01-012021-12-31 C008999 NORTHPARK, Distribution, Unattended 2021-12-31 C008999 See footnote for allocation method details, 2021-01-012021-12-31 C008999 ferc:DecemberMember 0 2021-01-012021-12-31 C008999 LAKEOVER, RAY BRASWELL 500KV LN 511 [7130], Steel Pole, 954 ACSR 2021-01-012021-12-31 C008999 VICKSBURG/NORTH, Distribution, Unattended 2021-12-31 C008999 HORN LAKE, MEMPHIS 161KV LN 149 (TVA TIE) [5960], Wood H-Frame, 666 ACSR 2021-01-012021-12-31 C008999 GERALD ANDRUS SES, TINNIN ROAD 230KV LN 204 [6901], Wood H-Frame, 1272 ACSR 2021-01-012021-12-31 C008999 GM-39-3E08-C4 Capacitor Install Ree 2021-01-012021-12-31 C008999 PELAHATCHIE, Distribution, Unattended 2021-12-31 C008999 Pelahatchie - Rankin 115kV CAP 2021-01-012021-12-31 C008999 Choctaw Unit 1 341 2021-01-012021-12-31 C008999 BWSES: J2200 AT1 Spare Life Extend 2021-01-012021-12-31 C008999 ferc:DecemberMember Entergy Mississippi, LLC 2021-01-012021-12-31 C008999 HERNANDO - 251 HWY 51 N - ASSOCIATEferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 0ferc:JulyMember 2021-01-012021-12-31 C008999 SHELBY SS, Transmission, Unattended 2021-12-31 C008999 Byram Replace Breaker FJ04 2021-01-012021-12-31 C008999 Federal Uemployment Tax, Federal Tax, , 2021-12-31 C008999 ferc:PayrollTaxMember 2021-12-31 C008999 ferc:ElectricUtilityMember 2020 - VICKSBURG - VICKSBURG EAST - 2021-01-012021-12-31 C008999 INDIANOLA 115 SUB, Distribution, Unattended 2021-12-31 C008999 VICKSBURG/OPENWOOD, Distribution, Unattended 2021-12-31 C008999 SL-37 Municipal Street Lighting 2021-01-012021-12-31 C008999 ferc:StateTaxMember 2021-01-012021-12-31 C008999 3.85% Series 2 2021-01-012021-12-31 C008999 State Income Tax, State Tax, , 2021-12-31 C008999 PAL-17 Private Area Lighting 2021-01-012021-12-31 C008999 Asset Retirement Obligation - Fossil 2021-01-012021-12-31 C008999 ferc:OtherUtilityOrNonutilityMember 2020-12-31 C008999 Asset Suite/AIMM Repl - Supply Chaiferc:ElectricUtilityMember 2021-12-31 C008999 Greenbrook to Snowden Park 115kv Lnferc:ElectricUtilityMember 2021-12-31 C008999 Winona-623 SAWYER RD EXT WINONA,MS-ferc:ElectricUtilityMember 2021-12-31 C008999 MILL STREET, Distribution, Unattended 2021-12-31 C008999 Other Accounts (Specify, provide details in footnote): 2021-01-012021-12-31 C008999 Formula Rate Plan Revenue Increase MPSC Docket No. 2018-UN-205 2021-01-012021-12-31 C008999 Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff, Docket No. ER19-652 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember Greenville SE Install circuit sw. o 2021-12-31 C008999 GREENVILLE/NORTH, Distribution, Unattended 2021-12-31 C008999 HOLLANDALE, Distribution, Unattended 2021-12-31 C008999 State Unemployment Tax, Unemployment Tax, , 2021-12-31 C008999 Solar DesotoCounty 341 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember SNOWDEN PARK DIST. ROW 2021-12-31 C008999 Attala Unit 1 341 2021-01-012021-12-31 C008999 Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff, Docket No. ER21-1720 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember Federal Excise Tax, Federal Tax, , 2021-01-012021-12-31 C008999 FREEPORT, Transmission, Unattended 2021-12-31 C008999 ferc:DirectPayrollDistributionMember Miscellaneous Deferred Debits (Account 186) 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember Advanced DMS 2021-12-31 C008999 BOVINA, Distribution, Unattended 2021-12-31 C008999 JACKSON/NORTH, Distribution, Unattended 2021-01-012021-12-31 C008999 Changes in money pool payable - net 2021-01-012021-12-31 C008999 GREENWOOD, Distribution, Unattended 2021-12-31 C008999 ferc:ElectricUtilityMember Gallatin: rpl FX20 & add FX10 Fdr  2021-01-012021-12-31 C008999 AMI Sales and Rev BIEferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 Greenville Replace Breaker 3E08, J4ferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 RAY BRASWELL EHV, Transmission, Unattended 2021-12-31 C008999 Qualified Pension funded status 2021-12-31 C008999 Ad Valorem Tax - MS, Other Ad Valorem Tax, ,ferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember Midnight: rpl ABS J0348 & Steel Bus 2021-12-31 C008999 ferc:OtherAdValoremTaxMember 2021-12-31 C008999 LED-2 LED Street and Area  Lighting 2021-01-012021-12-31 C008999 FootnoteDataAbstract 2021-01-012021-12-31 C008999 MOORHEAD, Distribution, Unattended 2021-12-31 C008999 GA1 WaterWallTube & Furn Hopp Bottoferc:ElectricUtilityMember 2021-12-31 C008999 ferc:ElectricUtilityMember 2021 SHN JXSNSW-KINGSW - 2 RCs 2021-01-012021-12-31 C008999 EMI Sunflower County SolarOversight 2021-01-012021-12-31 C008999 ferc:OtherStateTaxMember 2021-01-012021-12-31 C008999 Other Deductions (Account 4265)ferc:DirectPayrollDistributionMember 2021-01-012021-12-31 C008999 CRENSHAW, Distribution, Unattended 2021-01-012021-12-31 C008999 JONESTOWN SS, Transmission, Unattended 2021-01-012021-12-31 C008999 CLINTON INDUSTRIAL, Distribution, Unattended 2021-12-31 C008999 MISO Financial Transmission Rights Mark-to-Market 2021-01-012021-12-31 C008999 VICKSBURG, Distribution, Unattended 2021-01-012021-12-31 C008999 CHARITY CHURCH/JACKSON, Distribution, Unattended 2021-01-012021-12-31 C008999 Federal Uemployment Tax, Federal Tax, , 2020-12-31 C008999 ferc:CurrentYearMemberferc:SulfurDioxideMember 2020-12-31 C008999 2020 Planning CL20-005V Rebuild R1ferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 Lakeover-Hinds 230kV CAP 2021-01-012021-12-31 C008999 YAZOO CITY MUNICIPAL SS, Transmission, Unattended 2021-12-31 C008999 Attala Unit 1 342 2021-01-012021-12-31 C008999 Distribution 365.3 2021-01-012021-12-31 C008999 Haley R. Fisackerly - President and Chief Executive Officer of Entergy Mississippi 2021-01-012021-12-31 C008999 SCHLATER, Distribution, Unattended 2021-01-012021-12-31 C008999 ferc:ElectricPlantHeldForFutureUseMemberferc:ElectricUtilityMember 2020-12-31 C008999 WESSON, Distribution, Unattended 2021-12-31 C008999 IPS-26 Irrigation Pumping Power 2021-01-012021-12-31 C008999 Baxter Wilson Com 316 2021-01-012021-12-31 C008999 ferc:GenerationSubstationMember 2021-12-31 C008999 System aircraft 2021-01-012021-12-31 C008999 GM-39-3R02-RC7 Capacitor removal Hiferc:ElectricUtilityMember 2021-12-31 C008999 Distribution 366 2021-01-012021-12-31 C008999 Transmission 352 2021-01-012021-12-31 C008999 ferc:Quarter4Member 0 2021-01-012021-12-31 C008999 Attala Unit 1 343 2021-01-012021-12-31 C008999 Section 263A 2020-12-31 C008999 ferc:StateTaxMemberferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 SILVER CREEK, Distribution, Unattended 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember Midnight: rpl ABS J0348 & Steel Bus 2021-01-012021-12-31 C008999 Byram replace FJ05 & RTU Grid Modferc:ElectricUtilityMember 2021-12-31 C008999 PICKENS, Transmission, Unattended 2021-12-31 C008999 Undistributed overheadferc:ElectricUtilityMember 2021-12-31 C008999 Miscellaneous 2021-01-012021-12-31 C008999 ferc:IncomeTaxMember 2020-12-31 C008999 ferc:ElectricUtilityMember Add Ckt. 9A06  to Poleline for Seco 2021-01-012021-12-31 C008999 Distribution 364 2021-01-012021-12-31 C008999 TUNICA 230/115 SUB, Transmission, Unattended 2021-01-012021-12-31 C008999 Independence Com 316 2021-01-012021-12-31 C008999 BROOKHAVEN, Distribution, Unattended 2021-12-31 C008999 Baxter Wilson Com 312 2021-01-012021-12-31 C008999 LAKEOVER, YANDELL RD 230KV LN 235 [2335], Wood H-Frame, 1272 ACSR 2021-01-012021-12-31 C008999 Transmission 356.2 2021-01-012021-12-31 C008999 YANDELL RD, CATLETT 230KV LN 234 [2334], Steel Pole, 1272 ACSR 2021-01-012021-12-31 C008999 Mississippi Power & Light Co. 2020-12-31 C008999 ferc:AugustMember 0 2021-01-012021-12-31 C008999 Ad Valorem Tax - MS, Other Ad Valorem Tax, , 2021-01-012021-12-31 C008999 Corporate Franchise Tax-AR, Franchise Tax, , 2021-01-012021-12-31 C008999 Entergy Mississippi, LLCferc:JuneMember 2021-01-012021-12-31 C008999 FERNWOOD, Distribution, Unattended 2021-12-31 C008999 Terra Miss Nitrogen , OS , 2021-01-012021-12-31 C008999 ferc:SeveranceTaxMember 2021-01-012021-12-31 C008999 DSL-16 Directional Security  Lighting 2021-01-012021-12-31 C008999 Gas Hinds 2021-01-012021-12-31 C008999 ferc:OtherAdValoremTaxMember 2021-01-012021-12-31 C008999 Jackson, W: rpl RTU 2021-01-012021-12-31 C008999 REX BROWN 115 SWYD, Distribution, Unattended 2021-01-012021-12-31 C008999 RS-38C Residential Service 2021-01-012021-12-31 C008999 Federal Excise Tax, Federal Tax, , 2021-12-31 C008999 ferc:ElectricUtilityMember Whitfield: add Ckt Sw, rpl T1 Diff 2021-01-012021-12-31 C008999 Electric Deferred Fuel Under-Recovery 2021-12-31 C008999 Contra UA 398_RES 2021-01-012021-12-31 C008999 MAGEE, Distribution, Unattended 2021-01-012021-12-31 C008999 ferc:DistributionSubstationMember 2021-12-31 C008999 Distribution 373 2021-01-012021-12-31 C008999 Increases (Decreases) from Sales of Donations Received from Stockholders 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember HN1 - Hinds LTSA Capital 2021-01-012021-12-31 C008999 GREENBROOK, Distribution, Unattended 2021-01-012021-12-31 C008999 ferc:OtherAdValoremTaxMemberferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 2020-SuccessAudit-SA20M011-Southaveferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 ScheduleHydroelectricGeneratingPlantStatisticsAbstract 2021-01-012021-12-31 C008999 LIVINGSTON ROAD/JACKSON, Distribution, Unattended 2021-01-012021-12-31 C008999 Long-Term Incentive Plan 2021-01-012021-12-31 C008999 SHELBY SS, Transmission, Unattended 2021-01-012021-12-31 C008999 Contra UA 391.1_RES 2021-01-012021-12-31 C008999 ferc:OtherFederalTaxMemberferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 MINTER CITY SS, Transmission, Unattended 2021-12-31 C008999 ferc:CurrentYearMemberferc:SulfurDioxideMember 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember Jackson - Hwy LED Lighting 2021-12-31 C008999 GM-Guild 33-GK01-Focus Rebuild-Fore 2021-01-012021-12-31 C008999 GM-39-3R02-C11 Capacitor Install Hiferc:ElectricUtilityMember 2021-12-31 C008999 ferc:FederalInsuranceTaxMember 2021-01-012021-12-31 C008999 RS-38C Residential Service 2021-01-012021-12-31 C008999 GA1 WaterWallTube & Furn Hopp Botto 2021-01-012021-12-31 C008999 CLARKSDALE, Distribution, Unattended 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember MS Trans Off/Stor Facility Design 2021-01-012021-12-31 C008999 GLEN ALLAN, Distribution, Unattended 2021-01-012021-12-31 C008999 FP# F1PPU27609-Brookhaven-West McCoferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 Contra UA 391.3_RES 2021-01-012021-12-31 C008999 Rex Brown Unit 1 316_RES 2021-01-012021-12-31 C008999 Mississippi Power & Light Co.ferc:CapitalContributionMember 2021-01-012021-12-31 C008999 Independence Com 314 2021-01-012021-12-31 C008999 FC20M036 - FOCUS - 8F05 - FJ669 2021-01-012021-12-31 C008999 NATCHEZ SWYD, Transmission, Unattended 2021-12-31 C008999 Income Taxes 2021-01-012021-12-31 C008999 Other expenses incurred in connection wiht various filings before the FERC 2021-12-31 C008999 Bowling Green - Durant 115kV CAPferc:ElectricUtilityMember 2021-12-31 C008999 Vegetation Management Rider MPSC Docket No. 2018-UN-205 2021-12-31 C008999 Choctaw purchase - escrow funds 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember Other general and intangible plant 2021-12-31 C008999 ferc:AfterThreeYearsMemberferc:SulfurDioxideMember 2021-12-31 C008999 IPS-26 Irrigation Pumping Power 2021-01-012021-12-31 C008999 LAKEOVER, REX BROWN EAST 230KV LN 219 [6183], Steel Tower, 1780 ACSR 2021-01-012021-12-31 C008999 HERNANDO, Distribution, Unattended 2021-01-012021-12-31 C008999 MISO Financial Transmission Rights Mark-to-Market 2021-12-31 C008999 Johns-Manville: E&D J0467 Bay Upgdferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 EDWARDS, Distribution, Unattended 2021-01-012021-12-31 C008999 DSL-16 Directional Security  Lighting 2021-01-012021-12-31 C008999 State Unemployment Tax, Unemployment Tax, , 2020-12-31 C008999 GRENADA, Distribution, Unattended 2021-01-012021-12-31 C008999 JACKSON/NORTHWEST, Distribution, Unattended 2021-01-012021-12-31 C008999 Horn Lake-Nail Road-Reiner Developmferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 ferc:SalesAndUseTaxMember 2020-12-31 C008999 WESSON, Distribution, Unattended 2021-01-012021-12-31 C008999 Paul D. Hinnenkamp - Executive Vice President and Chief Operating Officer 2021-01-012021-12-31 C008999 Delta Unit 1 314_RES 2021-01-012021-12-31 C008999 ferc:RealEstateTaxMember 2021-12-31 C008999 ScheduleCapitalStockAbstract 2021-01-012021-12-31 C008999 ferc:FuelTaxMember 2021-01-012021-12-31 C008999 ferc:CurrentYearMemberferc:SulfurDioxideMember 2021-12-31 C008999 MOON LAKE SS, Transmission, Unattended 2021-01-012021-12-31 C008999 RANKIN INDTRL./JACKSON, Distribution, Unattended 2021-12-31 C008999 FP# F1PPU27609-FLI-Brookhaven-Westferc:ElectricUtilityMember 2021-12-31 C008999 Federal Excise Tax, Federal Tax, , 2020-12-31 C008999 Asset Retirement Obligation - Fossil 2021-12-31 C008999 2021-Magee-Mendenhall-Relocate Faciferc:ElectricUtilityMember 2021-12-31 C008999 3.25% Series 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember 2020 - SOUTHAVEN - PLUM POINT - CHU 2021-01-012021-12-31 C008999 Winona-623 SAWYER RD EXT WINONA,MS- 2021-01-012021-12-31 C008999 Clinton Ind: rpl Ckt Sw & Upgd Bayferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 Energy Efficiency Rider Under-Recovery 2021-12-31 C008999 Mississippi ITC 2021-01-012021-12-31 C008999 Delta Common 314_RES 2021-01-012021-12-31 C008999 ferc:OtherUtilityOrNonutilityMember 2021-12-31 C008999 CANTON/SOUTH, Distribution, Unattended 2021-12-31 C008999 Johns-Manville: E&D J0467 Bay Upgdferc:ElectricUtilityMember 2021-12-31 C008999 ferc:RealEstateTaxMemberferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 Downtown Jackson - Replace 500 KVA 2021-01-012021-12-31 C008999 ferc:ReactiveSupplyAndVoltageMember 2021-01-012021-12-31 C008999 ferc:Quarter1Member Entergy Mississippi, LLC 2021-01-012021-12-31 C008999 PAL-17 Private Area Lighting 2021-01-012021-12-31 C008999 Ad Valorem Tax Adjustment Rider MPSC Docket No. 2014-UN-132 2020-12-31 C008999 COUNTRY CLUB/JACKSON, Distribution, Unattended 2021-12-31 C008999 SHELBY, Distribution, Unattended 2021-12-31 C008999 2020 Planning CL20-005V Rebuild R1 2021-01-012021-12-31 C008999 ferc:SeptemberMember Entergy Mississippi, LLC 2021-01-012021-12-31 C008999 ferc:UnemploymentTaxMemberferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 ATTALA, Transmission, Unattended 2021-12-31 C008999 Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff, Docket No. ER17-215 2021-01-012021-12-31 C008999 MISO Financial Transmission Rights Mark-to-Market 2021-01-012021-12-31 C008999 Other Reconciling Items - See footnote detail 2021-01-012021-12-31 C008999 Delta Unit 2 314_RES 2021-01-012021-12-31 C008999 STAR, Distribution, Unattended 2021-01-012021-12-31 C008999 2020 Planning SE17-012A Regs/RC RRE 2021-01-012021-12-31 C008999 ferc:FebruaryMember 0 2021-01-012021-12-31 C008999 CHARLESTON, Distribution, Unattended 2021-12-31 C008999 VICKSBURG/NORTH, Distribution, Unattended 2021-01-012021-12-31 C008999 MS Trans Off/Stor Facility Design 2021-01-012021-12-31 C008999 2020 - Madison-Yandell-GY01 & GY05- 2021-01-012021-12-31 C008999 2020-Madison-Hoy Rd-Natchez Trace @ferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 HAZLEHURST, Distribution, Unattended 2021-12-31 C008999 Other transmission and distribution substation plantferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 2020 Planning CL20-005V New Build N 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember Entergy Services, LLC, Other Allocated Tax, , 2021-01-012021-12-31 C008999 TERRY, Distribution, Unattended 2021-01-012021-12-31 C008999 GS-298 General Lighting and Power 2021-01-012021-12-31 C008999 Other expenses incurred in connection with MISO and other transmission related FERC dockets 2021-12-31 C008999 Midcontinent Independent System Operator Inc 2021-01-012021-12-31 C008999 Oil Baxter Wilson 2021-01-012021-12-31 C008999 HORN LAKE, FREEPORT 230KV LN 216 [5942], Wood H-Frame, 1272 ACSR 2021-01-012021-12-31 C008999 Ad Valorem Tax - AR, Other Ad Valorem Tax, ,ferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 ferc:Quarter2Member 0 2021-01-012021-12-31 C008999 RS-38W Residential Water Heating Service 2021-01-012021-12-31 C008999 Entergy Power & Light Company 2021-01-012021-12-31 C008999 Rex Brown Common 311 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember Snowden Park-Bld 115kV Sub-Scoping 2021-12-31 C008999 Hazlehurst add circuit switchersferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 Vegetation Management Rider MPSC Docket No. 2018-UN-205 2021-01-012021-12-31 C008999 PORT GIBSON, Distribution, Unattended 2021-01-012021-12-31 C008999 CHURCH ROAD, Distribution, Unattended 2021-01-012021-12-31 C008999 Pelahatchie - Rankin 115kV CAPferc:ElectricUtilityMember 2021-12-31 C008999 ferc:FederalTaxMemberferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 2020 - MADISON - CANTON - 6C07 - QFferc:ElectricUtilityMember 2021-12-31 C008999 GM-39-3E08-C4 Capacitor Install Reeferc:ElectricUtilityMember 2021-12-31 C008999 Natchez 315_RES 2021-01-012021-12-31 C008999 Transmission 356.3 2021-01-012021-12-31 C008999 GRENADA/SOUTH, Distribution, Unattended 2021-12-31 C008999 LARSON ST/JACKSON, Distribution, Unattended 2021-01-012021-12-31 C008999 BRANDON, Distribution, Unattended 2021-12-31 C008999 KINGSWOOD/JACKSON, Distribution, Unattended 2021-01-012021-12-31 C008999 PICKENS, Distribution, Unattended 2021-01-012021-12-31 C008999 ROLLING FORK, Distribution, Unattended 2021-01-012021-12-31 C008999 GM-39-3R02-C11 Capacitor Install Hi 2021-01-012021-12-31 C008999 WINONA, Distribution, Unattended 2021-12-31 C008999 GRENADA, Distribution, Unattended 2021-12-31 C008999 RFL-16 Rural Flood Lighting 2021-01-012021-12-31 C008999 CANTON/SOUTH, Distribution, Unattended 2021-01-012021-12-31 C008999 UFL-16 Urban Flood Lighting 2021-01-012021-12-31 C008999 DELTA SWYD, Transmission, Unattended 2021-01-012021-12-31 C008999 ferc:OtherUtilityOrNonutilityMember Mississippi ITC 2020-12-31 C008999 EML: 115-13.8 | 20MVA (Marvell) 2021-01-012021-12-31 C008999 ferc:LocalTaxMember 2021-01-012021-12-31 C008999 MISO Sch 1 Sched/Sys Ctrl/Disp 2021-01-012021-03-31 C008999 Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff, Docket No. ER14-649 2021-01-012021-12-31 C008999 MAGEE, Distribution, Unattended 2021-12-31 C008999 EML:115-4.16 | 12.5MVA | JTreatmentferc:ElectricUtilityMember 2021-12-31 C008999 EML C Spire - Northern Routeferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 Delta Unit 2 312_RES 2021-01-012021-12-31 C008999 Natchez 310.2_RES 2021-01-012021-12-31 C008999 Hazlehurst add circuit switchers 2021-01-012021-12-31 C008999 Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff, Docket No. ER21-262 2021-01-012021-12-31 C008999 FRANKLIN EHV, Transmission, Unattended 2021-12-31 C008999 Jackson - Hwy LED Lighting 2021-01-012021-12-31 C008999 Attala Common 346 2021-01-012021-12-31 C008999 AMI - DMS/OMS - Software - Rel 4-5ferc:ElectricUtilityMember 2021-12-31 C008999 NATCHEZ, Distribution, Unattended 2021-01-012021-12-31 C008999 Grand Gulf Over-Recovery MPSC Docket No. 1984-UN-4620 2021-12-31 C008999 GRAND GULF TRANSMISSION, Transmission, Unattended 2021-12-31 C008999 B(4), SERC Dues 2021-01-012021-12-31 C008999 Distribution 360.2 2021-01-012021-12-31 C008999 EMI New Nuclear, LLC 2021-01-012021-12-31 C008999 FLORA, Distribution, Unattended 2021-12-31 C008999 ferc:ElectricUtilityMemberferc:ElectricPlantInServiceMember 2021-12-31 C008999 CF Industries Nitrogen, LLC , OS , 2021-01-012021-12-31 C008999 MCADAMS EHV, Transmission, Unattended 2021-12-31 C008999 Undistributed overheadferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 Delta Common 310.2 2021-01-012021-12-31 C008999 ferc:OtherLicenseAndFeesTaxMember 2021-12-31 C008999 ferc:ElectricUtilityMember FC20M036 - FOCUS - 8F05 - FJ669 2021-01-012021-12-31 C008999 CLINTON [MS], Distribution, Unattended 2021-12-31 C008999 RALEIGH, Distribution, Unattended 2021-12-31 C008999 ferc:PropertyTaxMember 2021-12-31 C008999 Electric Deferred Fuel Over-Recovery 2021-01-012021-12-31 C008999 ferc:OtherTaxMember 2021-01-012021-12-31 C008999 ATTALA PLANT, Transmission, Unattended 2021-01-012021-12-31 C008999 Delta Unit 1 316_RES 2021-01-012021-12-31 C008999 FAYETTE 2021-01-012021-12-31 C008999 SARDIS, Distribution, Unattended 2021-12-31 C008999 Federal Income Tax, Federal Tax, , 2021-01-012021-12-31 C008999 Oil Independence 2021-01-012021-12-31 C008999 ferc:OtherStateTaxMember 2021-12-31 C008999 SPRING RIDGE ROAD, Distribution, Unattended 2021-12-31 C008999 ferc:ElectricUtilityMember 2020-12-31 C008999 DURANT, Distribution, Unattended 2021-12-31 C008999 ferc:ElectricUtilityMember Lakeover-Hinds 230kV CAP 2021-01-012021-12-31 C008999 Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff, Docket No. ER16-1322 2021-01-012021-12-31 C008999 2021-01-012021-03-31 C008999 ferc:SalesAndUseTaxMemberferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 Electric Deferred Fuel Under-Recovery 2021-01-012021-12-31 C008999 Attala 2021-01-012021-12-31 C008999 MPSC  - Docket No. 2009-UN-388 - Attorney General Litigation 2021-01-012021-12-31 C008999 NESBIT, Distribution, Unattended 2021-01-012021-12-31 C008999 GM-Guild 33-FA06-Rebuild-Cleary Rdferc:ElectricUtilityMember 2021-12-31 C008999 Transmission 353 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember 2021 Planning CV20-002A New Build N 2021-12-31 C008999 CLINTON INDUSTRIAL, Distribution, Unattended 2021-01-012021-12-31 C008999 ferc:CurrentYearMemberferc:NitrogenOxideMember 2021-01-012021-12-31 C008999 Leo P. Denault 2021-01-012021-12-31 C008999 BOWLING GREEN SS, Transmission, Unattended 2021-12-31 C008999 State Use Tax, Sales And Use Tax, , 2021-12-31 C008999 Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff, Docket No. ER18-1982 2021-01-012021-12-31 C008999 2020-Madison-Hoy Rd-Natchez Trace @ferc:ElectricUtilityMember 2021-12-31 C008999 BYRAM, Distribution, Unattended 2021-01-012021-12-31 C008999 CSD Workforce Management System 2021-01-012021-12-31 C008999 ScheduleEnergyStorageOperationsLargePlantsAbstract 2021-01-012021-12-31 C008999 ferc:LandAndRightsMember Land and Land Rights Under $250,000 2021-01-012021-12-31 C008999 2020-SuccessAudit-SA20M011-Southaveferc:ElectricUtilityMember 2021-12-31 C008999 ferc:NovemberMember 0 2021-01-012021-12-31 C008999 IT hardware applications/service contracts 2021-01-012021-12-31 C008999 LELAND, Distribution, Unattended 2021-12-31 C008999 LUCKNEY, Distribution, Unattended 2021-01-012021-12-31 C008999 Other transmission lines plant 2021-01-012021-12-31 C008999 ferc:PenaltyTaxMemberferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 PORT GIBSON, Distribution, Unattended 2021-12-31 C008999 GGNS: E&D ST-21 Xfmr Bay Upgdferc:ElectricUtilityMember 2021-12-31 C008999 ferc:ExciseTaxMember 2020-12-31 C008999 ferc:TransmissionSubstationMember 2021-12-31 C008999 Gerald Andrus 315 2021-01-012021-12-31 C008999 Power Management Rider Under-Recovery MPSC Docket No. 2014-UN-132 2020-12-31 C008999 GGNS, BWSES 500KV LN 507 [5620], Steel Tower, 954 ACSR 2021-01-012021-12-31 C008999 RAY BRASWELL, NORRELL 230KV LN 240 [2340], Steel Pole, 1272 ACSR 2021-01-012021-12-31 C008999 GRANTS FERRY, Distribution, Unattended 2021-12-31 C008999 State Excise Tax, Excise Tax, ,ferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 Pickens replace breaker J1708, line 2021-01-012021-12-31 C008999 Ad Valorem Tax - MS, Other Ad Valorem Tax, , 2021-12-31 C008999 MCCOMB, Distribution, Unattended 2021-01-012021-12-31 C008999 Independence Un 2 316 2021-01-012021-12-31 C008999 NORTHPARK, Distribution, Unattended 2021-01-012021-12-31 C008999 Contract Rates 2021-01-012021-12-31 C008999 Other production plantferc:ElectricUtilityMember 2021-12-31 C008999 Non-Expense Accrued Labor 2021-12-31 C008999 ferc:ElectricUtilityMember Jackson, S: E&D J4674 Bay Upgrade 2021-01-012021-12-31 C008999 Corporate Franchise Tax-AR, Franchise Tax, ,ferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 DREW [MS], Distribution, Unattended 2021-12-31 C008999 FLORENCE, Distribution, Unattended 2021-12-31 C008999 Formula Rate Plan 2021 Settlement MPSC Docket No. 2018-UN-205 Amort 12 months beg June 2021 2021-12-31 C008999 ferc:ElectricUtilityMemberferc:AdValoremTaxMember 2021-01-012021-12-31 C008999 ferc:UnemploymentTaxMember 2020-12-31 C008999 COUNTRY CLUB/JACKSON, Distribution, Unattended 2021-01-012021-12-31 C008999 All 161 kV Lines, , , 2021-01-012021-12-31 C008999 Natchez 314_RES 2021-01-012021-12-31 C008999 Downtown Jackson - Replace 1500 KVAferc:ElectricUtilityMember 2021-12-31 C008999 ISES Acquisition Adjustment 2021-01-012021-12-31 C008999 Vegetation Management Rider MPSC Docket No. 2018-UN-205 2020-12-31 C008999 ferc:OtherTaxesAndFeesMember 2021-01-012021-12-31 C008999 2.55% Series 2021-12-31 C008999 Jackson Gas Light Company 2021-01-012021-12-31 C008999 Undistributed overhead 2021-01-012021-12-31 C008999 CRYSTAL SPRINGS, Distribution, Unattended 2021-01-012021-12-31 C008999 Entergy Arkansas, LLC , LU , 2021-01-012021-12-31 C008999 0ferc:JanuaryMember 2021-01-012021-12-31 C008999 ServiceNow Enhancements 2021-01-012021-12-31 C008999 Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff, Docket No. ER21-915 2021-01-012021-12-31 C008999 GM-39-3R02-C11 Capacitor Install Hiferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember Regulatory Commission, Other Taxes, , 2021-01-012021-12-31 C008999 Baxter Wilson 2021-01-012021-12-31 C008999 GREENBROOK, Distribution, Unattended 2021-12-31 C008999 Byram replace FJ05 & RTU Grid Modferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 Deferred COVID-19 costs MPSC Docket No. 2018-AD-141 - Amort July 2021-June 2022 2021-12-31 C008999 Purchases/Transfers:ferc:NitrogenOxideMember 2021-01-012021-12-31 C008999 Income Taxes 2021-12-31 C008999 Marcus V. Brown 2021-01-012021-12-31 C008999 Mississippi Power & Light Company 2021-01-012021-12-31 C008999 ferc:UnemploymentTaxMember 2021-01-012021-12-31 C008999 2020-Rankin-Henderson Rd-E Metro Pkferc:ElectricUtilityMember 2021-12-31 C008999 Madison-Hwy 43-Expedition Point Dev 2021-01-012021-12-31 C008999 B(1), EPRI dues 3 2021-01-012021-12-31 C008999 ferc:ElectricPlantHeldForFutureUseMemberferc:ElectricUtilityMember 2021-12-31 C008999 Rex Brown Unit 1 314_RES 2021-01-012021-12-31 C008999 GREENVILLE/MIDTOWN, Distribution, Unattended 2021-01-012021-12-31 C008999 BYRAM, Distribution, Unattended 2021-12-31 C008999 Getwell-Twinkletown 230kV Cut-Inferc:ElectricUtilityMember 2021-12-31 C008999 GM-Guild 33-GK01-Rebuild-Brookwood 2021-01-012021-12-31 C008999 Choctaw Generating Station Over-Recovery - MPSC Docket No. 2018-UN-205 2020-12-31 C008999 ferc:ElectricUtilityMember 2020 - Jackson North - Jackson Nort 2021-01-012021-12-31 C008999 4.52% Series 2021-01-012021-12-31 C008999 GREENWOOD, Distribution, Unattended 2021-01-012021-12-31 C008999 CSD Workforce Management Systemferc:ElectricUtilityMember 2021-12-31 C008999 Deferred Attorney General Litigation Costs MPSC Docket No. 2009-UN-388 Amort 6 years beg April 2020 2020-12-31 C008999 State Use Tax, Sales And Use Tax, , 2020-12-31 C008999 Greenville TCEPA - Arcola 115kV CAP 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember A1A - GE LTSA Budget Cap 2020-2024 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember Yandell Sub Upgrades 2021-12-31 C008999 GM-Guild 33-GK01-Asset Op-Cap Bank 2021-01-012021-12-31 C008999 GS-298 MS Gen. Lghtg & Pwr Muni. Service 2021-01-012021-12-31 C008999 MCADAMS, ATTALA 230KV LN 210 D/C [6415], Steel Tower, 1272 ACSR 2021-01-012021-12-31 C008999 Defined Benefit Pension & Other Post Retirement Plans 2021-12-31 C008999 Dividends on common equity 2021-01-012021-12-31 C008999 INDIANOLA 115 SUB, Distribution, Unattended 2021-01-012021-12-31 C008999 INVERNESS, Distribution, Unattended 2021-01-012021-12-31 C008999 NATCHEZ/SOUTH, Distribution, Unattended 2021-01-012021-12-31 C008999 2020 Planning RK20-010V Rebuild R2ferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember 2021 RANKIN MORTON 6R02 55Q0022 2021-12-31 C008999 Non-Qualified Pension funded status 2020-12-31 C008999 JACKSON/NORTH, Distribution, Unattended 2021-12-31 C008999 Mark-to-Market 2021-12-31 C008999 SPO EML SunflowerTaxEquityPartneshpferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 Other transmission and distribution substation plantferc:ElectricUtilityMember 2021-12-31 C008999 ferc:ElectricUtilityMember Other distribution lines plant 2021-12-31 C008999 ScheduleTransmissionServiceAndGenerationInterconnectionStudyCostsAbstract 2021-01-012021-12-31 C008999 Receipts & Sales, Other State Tax, , 2020-12-31 C008999 A(3), Distribution Automation 2021-01-012021-12-31 C008999 LAKEOVER, REX BROWN WEST 230KV LN 218 [6184], Steel Tower, 1780 ACSR 2021-01-012021-12-31 C008999 UTICA, Distribution, Unattended 2021-12-31 C008999 EMI New Nuclear, LLC 2020-12-31 C008999 Independence Un 1 311 2021-01-012021-12-31 C008999 Delta Unit 2 316_RES 2021-01-012021-12-31 C008999 Deferred Electric Storm Restoration Costs 2021-12-31 C008999 Derivative Instruments and Hedging Activities 2021-12-31 C008999 Other production plant 2021-01-012021-12-31 C008999 STAR, Distribution, Unattended 2021-12-31 C008999 NATCHEZ SWYD, Transmission, Unattended 2021-01-012021-12-31 C008999 INDIANOLA 230/115 SUB, Transmission, Unattended 2021-01-012021-12-31 C008999 EML C Spire - Northern Route 2021-01-012021-12-31 C008999 GS-298 General Lighting and Power 2021-01-012021-12-31 C008999 REX BROWN 230 SWYD, Transmission, Unattended 2021-12-31 C008999 Northpark: Add 230/115kV-400MVA Autferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 ferc:ElectricUtilityMember Privilege License, Other Taxes, , 2021-01-012021-12-31 C008999 FRANKLIN, BOGALUSA (MS/LA ST LN) 500KV LN 510 (OPCO TIE) [5521], Steel Tower, 954 ACSR 2021-01-012021-12-31 C008999 ferc:PenaltyTaxMember 2021-01-012021-12-31 C008999 CHURCH ROAD, Distribution, Unattended 2021-12-31 C008999 MCCOMB/WEST, Distribution, Unattended 2021-01-012021-12-31 C008999 Distribution 367 2021-01-012021-12-31 C008999 Contra UA 393_RES 2021-01-012021-12-31 C008999 Other expenses incurred in connection with various filings before the MPSC 2021-01-012021-12-31 C008999 2021 FOCUS FC21M021 Natchez 8F05 Roferc:ElectricUtilityMember 2021-12-31 C008999 HOLLANDALE, Distribution, Unattended 2021-01-012021-12-31 C008999 NATCHEZ, Distribution, Unattended 2021-12-31 C008999 PLUM POINT, Distribution, Unattended 2021-01-012021-12-31 C008999 , , , 2020-12-31 C008999 ferc:ElectricUtilityMember Horn Lake-MS Hwy 301-Yazoo Developm 2021-12-31 C008999 Miscellaneous Current and Accrued Assets (Account 174) 2021-01-012021-12-31 C008999 ferc:OtherUtilityOrNonutilityMember Mississippi ITC 2021-12-31 C008999 ferc:ElectricUtilityMember 4% 2021-01-012021-12-31 C008999 BEECH GROVE SS, Transmission, Unattended 2021-01-012021-12-31 C008999 LED-2 LED Street and Area  Lighting 2021-01-012021-12-31 C008999 ferc:PropertyTaxMemberferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 Greenville SE Install circuit sw. o 2021-01-012021-12-31 C008999 CLINTON [MS], Distribution, Unattended 2021-01-012021-12-31 C008999 State Excise Tax, Excise Tax, , 2021-01-012021-12-31 C008999 GRAND GULF DISTRIBUTION, Distribution, Unattended 2021-01-012021-12-31 C008999 Getwell-Twinkletown 230kV Cut-Inferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 ferc:OtherTaxMember 2021-12-31 C008999 2020-Rankin-Henderson Rd-E Metro Pkferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 B-34 Intermediate General Service 2021-01-012021-12-31 C008999 , , , 2021-01-012021-12-31 C008999 NORTHSIDE DRIVE/JACKSON, Distribution, Unattended 2021-01-012021-12-31 C008999 Formula Rate Plan 2021 Settlement MPSC Docket No. 2018-UN-205 Amort 12 months beg June 2021 2021-01-012021-12-31 C008999 AMI Sales and Rev BIE 2021-01-012021-12-31 C008999 Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff, Docket No. ER21-2693 2021-01-012021-12-31 C008999 FLOWERS, Distribution, Unattended 2021-01-012021-12-31 C008999 Energy System Power Pool , OS , 2021-01-012021-12-31 C008999 Other working capital 2021-01-012021-12-31 C008999 Derivative Instruments and Hedging Activities 2020-12-31 C008999 BOLTON, Distribution, Unattended 2021-01-012021-12-31 C008999 Indianola-Itta Bena 115kv 2021-01-012021-12-31 C008999 PAL-17 Private Area Lighting 2021-01-012021-12-31 C008999 ferc:AugustMember Entergy Mississippi, LLC 2021-01-012021-12-31 C008999 T&D - Catlett 230kv Sub - Substatioferc:ElectricUtilityMember 2021-12-31 C008999 ferc:ElectricUtilityMember 2020 - VICKSBURG - VICKSBURG EAST - 2021-12-31 C008999 Horn Lake-Nail Road-Reiner Developm 2021-01-012021-12-31 C008999 Mark-to-Market 2020-12-31 C008999 ferc:NitrogenOxideMemberferc:ThreeYearsMember 2021-12-31 C008999 Steven W. Brady 2021-01-012021-12-31 C008999 2021 - Cleveland - Belzoni - 4H01 -ferc:ElectricUtilityMember 2021-12-31 C008999 Highway 51 Warehouse Relocationferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 GASES, LAKE VILLAGE BAGBY (MS/AR ST LN) 230KV LN 202 (OPCO TIE) [5540], Steel Tower, 1272 ACSR 2021-01-012021-12-31 C008999 CARTHAGE (MS), Distribution, Unattended 2021-01-012021-12-31 C008999 ferc:AfterThreeYearsMemberferc:NitrogenOxideMember 2021-12-31 C008999 VICKSBURG/EAST, Distribution, Unattended 2021-01-012021-12-31 C008999 Qualified Pension Settlement Cost Deferral MPSC Docket No. 2020-UA-91 Amort 120 months beg July 2021 2021-12-31 C008999 Attala Unit 1 344 2021-01-012021-12-31 C008999 FLI-SENATOBIA NETWORK-SENATOBIA-1H0 2021-01-012021-12-31 C008999 ferc:OtherUtilityMember Other (Specify) 2021-01-012021-12-31 C008999 GM-Guild 33-GK01-Rebuild-Brookwoodferc:ElectricUtilityMember 2021-12-31 C008999 FICA, Federal Tax, , 2020-12-31 C008999 Miscellaneous Deferred Debits (Account 186) 2021-01-012021-12-31 C008999 DURANT, Distribution, Unattended 2021-01-012021-12-31 C008999 EML Public EV Charging Pilot 2021-01-012021-12-31 C008999 Rex Brown Unit 1 312_RES 2021-01-012021-12-31 C008999 ferc:MiscellaneousOtherTaxMemberferc:ElectricUtilityMember 2021-01-012021-12-31 C008999 VICKSBURG/WEST, Distribution, Unattended 2021-01-012021-12-31 C008999 Asset Suite/AIMM Repl - Supply Chai 2021-01-012021-12-31 C008999 UFL-16 Urban Flood Lighting 2021-01-012021-12-31 C008999 CHOCTAW, Transmission, Unattended 2021-01-012021-12-31 utr:MWh utr:mi utr:MW utr:kV utr:Btu utr:Btu utr:kWh utr:kWh xbrli:pure utr:MVA iso4217:USD utr:kW iso4217:USD utr:T iso4217:USD utr:bbl utr:T iso4217:USD utr:MMBTU iso4217:USD utr:Mcf iso4217:USD utr:kWh utr:Mcf xbrli:pure utr:mi iso4217:USD utr:bbl
THIS FILING IS
Item 1:
An Initial (Original) Submission
OR
Resubmission No.

FERC FINANCIAL REPORT
FERC FORM No. 1: Annual Report of
Major Electric Utilities, Licensees
and Others and Supplemental
Form 3-Q: Quarterly Financial Report

These reports are mandatory under the Federal Power Act, Sections 3, 4(a), 304 and 309, and 18 CFR 141.1 and 141.400. Failure to report may result in criminal fines, civil penalties and other sanctions as provided by law. The Federal Energy Regulatory Commission does not consider these reports to be of confidential nature
Exact Legal Name of Respondent (Company)

Entergy Mississippi, LLC
Year/Period of Report

End of:
2021
/
Q4


INSTRUCTIONS FOR FILING FERC FORM NOS. 1 and 3-Q

GENERAL INFORMATION

  1. Purpose

    FERC Form No. 1 (FERC Form 1) is an annual regulatory requirement for Major electric utilities, licensees and others (18 C.F.R. § 141.1). FERC Form No. 3-Q ( FERC Form 3-Q) is a quarterly regulatory requirement which supplements the annual financial reporting requirement (18 C.F.R. § 141.400). These reports are designed to collect financial and operational information from electric utilities, licensees and others subject to the jurisdiction of the Federal Energy Regulatory Commission. These reports are also considered to be non-confidential public use forms.
  2. Who Must Submit

    Each Major electric utility, licensee, or other, as classified in the Commission’s Uniform System of Accounts Prescribed for Public Utilities, Licensees, and Others Subject To the Provisions of The Federal Power Act (18 C.F.R. Part 101), must submit FERC Form 1 (18 C.F.R. § 141.1), and FERC Form 3-Q (18 C.F.R. § 141.400).

    Note: Major means having, in each of the three previous calendar years, sales or transmission service that exceeds one of the following:
    1. one million megawatt hours of total annual sales,
    2. 100 megawatt hours of annual sales for resale,
    3. 500 megawatt hours of annual power exchanges delivered, or
    4. 500 megawatt hours of annual wheeling for others (deliveries plus losses).
  3. What and Where to Submit

    1. Submit FERC Form Nos. 1 and 3-Q electronically through the eCollection portal at https://eCollection.ferc.gov, and according to the specifications in the Form 1 and 3-Q taxonomies.
    2. The Corporate Officer Certification must be submitted electronically as part of the FERC Forms 1 and 3-Q filings.
    3. Submit immediately upon publication, by either eFiling or mail, two (2) copies to the Secretary of the Commission, the latest Annual Report to Stockholders. Unless eFiling the Annual Report to Stockholders, mail the stockholders report to the Secretary of the Commission at:
      Secretary
      Federal Energy Regulatory Commission 888 First Street, NE
      Washington, DC 20426
    4. For the CPA Certification Statement, submit within 30 days after filing the FERC Form 1, a letter or report (not applicable to filers classified as Class C or Class D prior to January 1, 1984). The CPA Certification Statement can be either eFiled or mailed to the Secretary of the Commission at the address above.

      The CPA Certification Statement should:
      1. Attest to the conformity, in all material aspects, of the below listed (schedules and pages) with the Commission's applicable Uniform System of Accounts (including applicable notes relating thereto and the Chief Accountant's published accounting releases), and
      2. Be signed by independent certified public accountants or an independent licensed public accountant certified or licensed by a regulatory authority of a State or other political subdivision of the U. S. (See 18 C.F.R. §§ 41.10-41.12 for specific qualifications.)

        Schedules
        Pages
        Comparative Balance Sheet 110-113
        Statement of Income 114-117
        Statement of Retained Earnings 118-119
        Statement of Cash Flows 120-121
        Notes to Financial Statements 122-123
    5. The following format must be used for the CPA Certification Statement unless unusual circumstances or conditions, explained in the letter or report, demand that it be varied. Insert parenthetical phrases only when exceptions are reported.

      “In connection with our regular examination of the financial statements of [COMPANY NAME] for the year ended on which we have reported separately under date of [DATE], we have also reviewed schedules [NAME OF SCHEDULES] of FERC Form No. 1 for the year filed with the Federal Energy Regulatory Commission, for conformity in all material respects with the requirements of the Federal Energy Regulatory Commission as set forth in its applicable Uniform System of Accounts and published accounting releases. Our review for this purpose included such tests of the accounting records and such other auditing procedures as we considered necessary in the circumstances.

      Based on our review, in our opinion the accompanying schedules identified in the preceding paragraph (except as noted below) conform in all material respects with the accounting requirements of the Federal Energy Regulatory Commission as set forth in its applicable Uniform System of Accounts and published accounting releases.” The letter or report must state which, if any, of the pages above do not conform to the Commission’s requirements. Describe the discrepancies that exist.
    6. Filers are encouraged to file their Annual Report to Stockholders, and the CPA Certification Statement using eFiling. Further instructions are found on the Commission’s website at https://www.ferc.gov/ferc-online/ferc-online/frequently-asked-questions-faqs-efilingferc-online.
    7. Federal, State, and Local Governments and other authorized users may obtain additional blank copies of FERC Form 1 and 3-Q free of charge from https://www.ferc.gov/general-information-0/electric-industry-forms.
  4. When to Submit

    FERC Forms 1 and 3-Q must be filed by the following schedule:

    1. FERC Form 1 for each year ending December 31 must be filed by April 18th of the following year (18 CFR § 141.1), and
    2. FERC Form 3-Q for each calendar quarter must be filed within 60 days after the reporting quarter (18 C.F.R. § 141.400).
  5. Where to Send Comments on Public Reporting Burden.

    The public reporting burden for the FERC Form 1 collection of information is estimated to average 1,168 hours per response, including the time for reviewing instructions, searching existing data sources, gathering and maintaining the data-needed, and completing and reviewing the collection of information. The public reporting burden for the FERC Form 3-Q collection of information is estimated to average 168 hours per response.

    Send comments regarding these burden estimates or any aspect of these collections of information, including suggestions for reducing burden, to the Federal Energy Regulatory Commission, 888 First Street NE, Washington, DC 20426 (Attention: Information Clearance Officer); and to the Office of Information and Regulatory Affairs, Office of Management and Budget, Washington, DC 20503 (Attention: Desk Officer for the Federal Energy Regulatory Commission). No person shall be subject to any penalty if any collection of information does not display a valid control number (44 U.S.C. § 3512 (a)).

GENERAL INSTRUCTIONS

  1. Prepare this report in conformity with the Uniform System of Accounts (18 CFR Part 101) (USofA). Interpret all accounting words and phrases in accordance with the USofA.
  2. Enter in whole numbers (dollars or MWH) only, except where otherwise noted. (Enter cents for averages and figures per unit where cents are important. The truncating of cents is allowed except on the four basic financial statements where rounding is required.) The amounts shown on all supporting pages must agree with the amounts entered on the statements that they support. When applying thresholds to determine significance for reporting purposes, use for balance sheet accounts the balances at the end of the current reporting period, and use for statement of income accounts the current year's year to date amounts.
  3. Complete each question fully and accurately, even if it has been answered in a previous report. Enter the word "None" where it truly and completely states the fact.
  4. For any page(s) that is not applicable to the respondent, omit the page(s) and enter "NA," "NONE," or "Not Applicable" in column (d) on the List of Schedules, pages 2 and 3.
  5. Enter the month, day, and year for all dates. Use customary abbreviations. The "Date of Report" included in the header of each page is to be completed only for resubmissions (see VII. below).
  6. Generally, except for certain schedules, all numbers, whether they are expected to be debits or credits, must be reported as positive. Numbers having a sign that is different from the expected sign must be reported by enclosing the numbers in parentheses.
  7. For any resubmissions, please explain the reason for the resubmission in a footnote to the data field.
  8. Do not make references to reports of previous periods/years or to other reports in lieu of required entries, except as specifically authorized.
  9. Wherever (schedule) pages refer to figures from a previous period/year, the figures reported must be based upon those shown by the report of the previous period/year, or an appropriate explanation given as to why the different figures were used.
  10. Schedule specific instructions are found in the applicable taxonomy and on the applicable blank rendered form.
Definitions for statistical classifications used for completing schedules for transmission system reporting are as follows:

FNS - Firm Network Transmission Service for Self. "Firm" means service that can not be interrupted for economic reasons and is intended to remain reliable even under adverse conditions. "Network Service" is Network Transmission Service as described in Order No. 888 and the Open Access Transmission Tariff. "Self" means the respondent.

FNO - Firm Network Service for Others. "Firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions. "Network Service" is Network Transmission Service as described in Order No. 888 and the Open Access Transmission Tariff.

LFP - for Long-Term Firm Point-to-Point Transmission Reservations. "Long-Term" means one year or longer and” firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions. "Point-to-Point Transmission Reservations" are described in Order No. 888 and the Open Access Transmission Tariff. For all transactions identified as LFP, provide in a footnote the termination date of the contract defined as the earliest date either buyer or seller can unilaterally cancel the contract.

OLF - Other Long-Term Firm Transmission Service. Report service provided under contracts which do not conform to the terms of the Open Access Transmission Tariff. "Long-Term" means one year or longer and “firm” means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions. For all transactions identified as OLF, provide in a footnote the termination date of the contract defined as the earliest date either buyer or seller can unilaterally get out of the contract.

SFP - Short-Term Firm Point-to-Point Transmission Reservations. Use this classification for all firm point-to-point transmission reservations, where the duration of each period of reservation is less than one-year.

NF - Non-Firm Transmission Service, where firm means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions.

OS - Other Transmission Service. Use this classification only for those services which can not be placed in the above-mentioned classifications, such as all other service regardless of the length of the contract and service FERC Form. Describe the type of service in a footnote for each entry.

AD - Out-of-Period Adjustments. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting periods. Provide an explanation in a footnote for each adjustment.

DEFINITIONS
  1. Commission Authorization (Comm. Auth.) -- The authorization of the Federal Energy Regulatory Commission, or any other Commission. Name the commission whose authorization was obtained and give date of the authorization.
  2. Respondent -- The person, corporation, licensee, agency, authority, or other Legal entity or instrumentality in whose behalf the report is made.

EXCERPTS FROM THE LAW

Federal Power Act, 16 U.S.C. § 791a-825r

Sec. 3. The words defined in this section shall have the following meanings for purposes of this Act, to with:

  1. ’Corporation' means any corporation, joint-stock company, partnership, association, business trust, organized group of persons, whether incorporated or not, or a receiver or receivers, trustee or trustees of any of the foregoing. It shall not include 'municipalities, as hereinafter defined;
  2. 'Person' means an individual or a corporation;
  3. 'Licensee, means any person, State, or municipality Licensed under the provisions of section 4 of this Act, and any assignee or successor in interest thereof;
  1. 'municipality means a city, county, irrigation district, drainage district, or other political subdivision or agency of a State competent under the Laws thereof to carry and the business of developing, transmitting, unitizing, or distributing power; ......
  1. "project' means. a complete unit of improvement or development, consisting of a power house, all water conduits, all dams and appurtenant works and structures (including navigation structures) which are a part of said unit, and all storage, diverting, or fore bay reservoirs directly connected therewith, the primary line or lines transmitting power there from to the point of junction with the distribution system or with the interconnected primary transmission system, all miscellaneous structures used and useful in connection with said unit or any part thereof, and all water rights, rights-of-way, ditches, dams, reservoirs, Lands, or interest in Lands the use and occupancy of which are necessary or appropriate in the maintenance and operation of such unit;

"Sec. 4. The Commission is hereby authorized and empowered
  1. 'To make investigations and to collect and record data concerning the utilization of the water 'resources of any region to be developed, the water-power industry and its relation to other industries and to interstate or foreign commerce, and concerning the location, capacity, development costs, and relation to markets of power sites; ... to the extent the Commission may deem necessary or useful for the purposes of this Act."

"Sec. 304.
  1. Every Licensee and every public utility shall file with the Commission such annual and other periodic or special* reports as the Commission may by rules and regulations or other prescribe as necessary or appropriate to assist the Commission in the proper administration of this Act. The Commission may prescribe the manner and FERC Form in which such reports shall be made, and require from such persons specific answers to all questions upon which the Commission may need information. The Commission may require that such reports shall include, among other things, full information as to assets and Liabilities, capitalization, net investment, and reduction thereof, gross receipts, interest due and paid, depreciation, and other reserves, cost of project and other facilities, cost of maintenance and operation of the project and other facilities, cost of renewals and replacement of the project works and other facilities, depreciation, generation, transmission, distribution, delivery, use, and sale of electric energy. The Commission may require any such person to make adequate provision for currently determining such costs and other facts. Such reports shall be made under oath unless the Commission otherwise specifies*.10
"Sec. 309.
  1. The Commission shall have power to perform any and all acts, and to prescribe, issue, make, and rescind such orders, rules and regulations as it may find necessary or appropriate to carry out the provisions of this Act. Among other things, such rules and regulations may define accounting, technical, and trade terms used in this Act; and may prescribe the FERC Form or FERC Forms of all statements, declarations, applications, and reports to be filed with the Commission, the information which they shall contain, and the time within which they shall be field..."

GENERAL PENALTIES

The Commission may assess up to $1 million per day per violation of its rules and regulations. See FPA § 316(a) (2005), 16 U.S.C. § 825o(a).


FERC FORM NO.
1

REPORT OF MAJOR ELECTRIC UTILITIES, LICENSEES AND OTHER
IDENTIFICATION
01 Exact Legal Name of Respondent

Entergy Mississippi, LLC
02 Year/ Period of Report


End of:
2021
/
Q4
03 Previous Name and Date of Change (If name changed during year)

/
04 Address of Principal Office at End of Period (Street, City, State, Zip Code)

308 East Pearl Street, Jackson, Mississippi 39201
05 Name of Contact Person

Gina G. Bellott
06 Title of Contact Person

Sr. Staff Accountant
07 Address of Contact Person (Street, City, State, Zip Code)

639 Loyola Avenue, New Orleans, Louisiana 70113
08 Telephone of Contact Person, Including Area Code

(504) 858-3276
09 This Report is An Original / A Resubmission

(1)
An Original

(2)
A Resubmission
10 Date of Report (Mo, Da, Yr)

04/15/2022
Annual Corporate Officer Certification
The undersigned officer certifies that:

I have examined this report and to the best of my knowledge, information, and belief all statements of fact contained in this report are correct statements of the business affairs of the respondent and the financial statements, and other financial information contained in this report, conform in all material respects to the Uniform System of Accounts.

01 Name

Kimberly A. Fontan
02 Title

Sr VP & Chief Accounting Officer
03 Signature

Kimberly A. Fontan
04 Date Signed (Mo, Da, Yr)

04/15/2022
Title 18, U.S.C. 1001 makes it a crime for any person to knowingly and willingly to make to any Agency or Department of the United States any false, fictitious or fraudulent statements as to any matter within its jurisdiction.


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
LIST OF SCHEDULES (Electric Utility)

Enter in column (c) the terms "none," "not applicable," or "NA," as appropriate, where no information or amounts have been reported for certain pages. Omit pages where the respondents are "none," "not applicable," or "NA".

Line No.
Title of Schedule
(a)
Reference Page No.
(b)
Remarks
(c)
ScheduleIdentificationAbstract
Identification
1
ScheduleListOfSchedulesAbstract
List of Schedules
2
1
ScheduleGeneralInformationAbstract
General Information
101
2
ScheduleControlOverRespondentAbstract
Control Over Respondent
102
3
ScheduleCorporationsControlledByRespondentAbstract
Corporations Controlled by Respondent
103
4
ScheduleOfficersAbstract
Officers
104
5
ScheduleDirectorsAbstract
Directors
105
6
ScheduleInformationOnFormulaRatesAbstract
Information on Formula Rates
106
7
ScheduleImportantChangesDuringTheQuarterYearAbstract
Important Changes During the Year
108
8
ScheduleComparativeBalanceSheetAbstract
Comparative Balance Sheet
110
9
ScheduleStatementOfIncomeAbstract
Statement of Income for the Year
114
10
ScheduleRetainedEarningsAbstract
Statement of Retained Earnings for the Year
118
12
ScheduleStatementOfCashFlowsAbstract
Statement of Cash Flows
120
12
ScheduleNotesToFinancialStatementsAbstract
Notes to Financial Statements
122
13
ScheduleStatementOfAccumulatedOtherComprehensiveIncomeAndHedgingActivitiesAbstract
Statement of Accum Other Comp Income, Comp Income, and Hedging Activities
122a
NA
14
ScheduleSummaryOfUtilityPlantAndAccumulatedProvisionsForDepreciationAmortizationAndDepletionAbstract
Summary of Utility Plant & Accumulated Provisions for Dep, Amort & Dep
200
15
ScheduleNuclearFuelMaterialsAbstract
Nuclear Fuel Materials
202
NA
16
ScheduleElectricPlantInServiceAbstract
Electric Plant in Service
204
17
ScheduleElectricPropertyLeasedToOthersAbstract
Electric Plant Leased to Others
213
NA
18
ScheduleElectricPlantHeldForFutureUseAbstract
Electric Plant Held for Future Use
214
19
ScheduleConstructionWorkInProgressElectricAbstract
Construction Work in Progress-Electric
216
20
ScheduleAccumulatedProvisionForDepreciationOfElectricUtilityPlantAbstract
Accumulated Provision for Depreciation of Electric Utility Plant
219
21
ScheduleInvestmentsInSubsidiaryCompaniesAbstract
Investment of Subsidiary Companies
224
22
ScheduleMaterialsAndSuppliesAbstract
Materials and Supplies
227
23
ScheduleAllowanceInventoryAbstract
Allowances
228
24
ScheduleExtraordinaryPropertyLossesAbstract
Extraordinary Property Losses
230a
NA
25
ScheduleUnrecoveredPlantAndRegulatoryStudyCostsAbstract
Unrecovered Plant and Regulatory Study Costs
230b
NA
26
ScheduleTransmissionServiceAndGenerationInterconnectionStudyCostsAbstract
Transmission Service and Generation Interconnection Study Costs
231
NA
27
ScheduleOtherRegulatoryAssetsAbstract
Other Regulatory Assets
232
28
ScheduleMiscellaneousDeferredDebitsAbstract
Miscellaneous Deferred Debits
233
29
ScheduleAccumulatedDeferredIncomeTaxesAbstract
Accumulated Deferred Income Taxes
234
30
ScheduleCapitalStockAbstract
Capital Stock
250
NA
31
ScheduleOtherPaidInCapitalAbstract
Other Paid-in Capital
253
32
ScheduleCapitalStockExpenseAbstract
Capital Stock Expense
254b
NA
33
ScheduleLongTermDebtAbstract
Long-Term Debt
256
34
ScheduleReconciliationOfReportedNetIncomeWithTaxableIncomeForFederalIncomeTaxesAbstract
Reconciliation of Reported Net Income with Taxable Inc for Fed Inc Tax
261
35
ScheduleTaxesAccruedPrepaidAndChargedDuringYearDistributionOfTaxesChargedAbstract
Taxes Accrued, Prepaid and Charged During the Year
262
36
ScheduleAccumulatedDeferredInvestmentTaxCreditsAbstract
Accumulated Deferred Investment Tax Credits
266
37
ScheduleOtherDeferredCreditsAbstract
Other Deferred Credits
269
38
ScheduleAccumulatedDeferredIncomeTaxesAcceleratedAmortizationPropertyAbstract
Accumulated Deferred Income Taxes-Accelerated Amortization Property
272
NA
39
ScheduleAccumulatedDeferredIncomeTaxesOtherPropertyAbstract
Accumulated Deferred Income Taxes-Other Property
274
40
ScheduleAccumulatedDeferredIncomeTaxesOtherAbstract
Accumulated Deferred Income Taxes-Other
276
41
ScheduleOtherRegulatoryLiabilitiesAbstract
Other Regulatory Liabilities
278
42
ScheduleElectricOperatingRevenuesAbstract
Electric Operating Revenues
300
43
ScheduleRegionalTransmissionServiceRevenuesAbstract
Regional Transmission Service Revenues (Account 457.1)
302
44
ScheduleSalesOfElectricityByRateSchedulesAbstract
Sales of Electricity by Rate Schedules
304
45
ScheduleSalesForResaleAbstract
Sales for Resale
310
46
ScheduleElectricOperationsAndMaintenanceExpensesAbstract
Electric Operation and Maintenance Expenses
320
47
SchedulePurchasedPowerAbstract
Purchased Power
326
48
ScheduleTransmissionOfElectricityForOthersAbstract
Transmission of Electricity for Others
328
49
ScheduleTransmissionOfElectricityByIsoOrRtoAbstract
Transmission of Electricity by ISO/RTOs
331
NA
50
ScheduleTransmissionOfElectricityByOthersAbstract
Transmission of Electricity by Others
332
51
ScheduleMiscellaneousGeneralExpensesAbstract
Miscellaneous General Expenses-Electric
335
52
ScheduleDepreciationDepletionAndAmortizationAbstract
Depreciation and Amortization of Electric Plant (Account 403, 404, 405)
336
53
ScheduleRegulatoryCommissionExpensesAbstract
Regulatory Commission Expenses
350
54
ScheduleResearchDevelopmentOrDemonstrationExpendituresAbstract
Research, Development and Demonstration Activities
352
55
ScheduleDistributionOfSalariesAndWagesAbstract
Distribution of Salaries and Wages
354
56
ScheduleCommonUtilityPlantAndExpensesAbstract
Common Utility Plant and Expenses
356
NA
57
ScheduleAmountsIncludedInIsoOrRtoSettlementAbstract
Amounts included in ISO/RTO Settlement Statements
397
58
SchedulePurchasesSalesOfAncillaryServicesAbstract
Purchase and Sale of Ancillary Services
398
59
ScheduleMonthlyTransmissionSystemPeakLoadAbstract
Monthly Transmission System Peak Load
400
60
ScheduleMonthlyIsoOrRtoTransmissionSystemPeakLoadAbstract
Monthly ISO/RTO Transmission System Peak Load
400a
NA
61
ScheduleElectricEnergyAccountAbstract
Electric Energy Account
401a
62
ScheduleMonthlyPeakAndOutputAbstract
Monthly Peaks and Output
401b
63
ScheduleSteamElectricGeneratingPlantStatisticsAbstract
Steam Electric Generating Plant Statistics
402
64
ScheduleHydroelectricGeneratingPlantStatisticsAbstract
Hydroelectric Generating Plant Statistics
406
NA
65
SchedulePumpedStorageGeneratingPlantStatisticsAbstract
Pumped Storage Generating Plant Statistics
408
NA
66
ScheduleGeneratingPlantStatisticsAbstract
Generating Plant Statistics Pages
410
NA
0
ScheduleEnergyStorageOperationsLargePlantsAbstract
Energy Storage Operations (Large Plants)
414
NA
67
ScheduleTransmissionLineStatisticsAbstract
Transmission Line Statistics Pages
422
68
ScheduleTransmissionLinesAddedAbstract
Transmission Lines Added During Year
424
69
ScheduleSubstationsAbstract
Substations
426
70
ScheduleTransactionsWithAssociatedAffiliatedCompaniesAbstract
Transactions with Associated (Affiliated) Companies
429
71
FootnoteDataAbstract
Footnote Data
450
NA
StockholdersReportsAbstract
Stockholders' Reports (check appropriate box)
Stockholders' Reports Check appropriate box:

Two copies will be submitted

No annual report to stockholders is prepared


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
GENERAL INFORMATION
1. Provide name and title of officer having custody of the general corporate books of account and address of office where the general corporate books are kept, and address of office where any other corporate books of account are kept, if different from that where the general corporate books are kept.

Kimberly A. Fontan

Senior Vice President and Chief Accounting Officer

639 Loyola Avenue, New Orleans, LA 70113
2. Provide the name of the State under the laws of which respondent is incorporated, and date of incorporation. If incorporated under a special law, give reference to such law. If not incorporated, state that fact and give the type of organization and the date organized.

State of Incorporation:
TX

Date of Incorporation:
2018-09-17

Incorporated Under Special Law:

3. If at any time during the year the property of respondent was held by a receiver or trustee, give (a) name of receiver or trustee, (b) date such receiver or trustee took possession, (c) the authority by which the receivership or trusteeship was created, and (d) date when possession by receiver or trustee ceased.

N/A

(a) Name of Receiver or Trustee Holding Property of the Respondent:

(b) Date Receiver took Possession of Respondent Property:

(c) Authority by which the Receivership or Trusteeship was created:

(d) Date when possession by receiver or trustee ceased:
4. State the classes or utility and other services furnished by respondent during the year in each State in which the respondent operated.

Mississippi - Electric Utility Service
5. Have you engaged as the principal accountant to audit your financial statements an accountant who is not the principal accountant for your previous year's certified financial statements?
(1)
Yes

(2)
No


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
CONTROL OVER RESPONDENT
1. If any corporation, business trust, or similar organization or a combination of such organizations jointly held control over the respondent at the end of the year, state name of controlling corporation or organization, manner in which control was held, and extent of control. If control was in a holding company organization, show the chain of ownership or control to the main parent company or organization. If control was held by a trustee(s), state name of trustee(s), name of beneficiary or beneficiaries for whom trust was maintained, and purpose of the trust.
As of December 31, 2021, all of the common membership interests in Entergy Mississippi are held by Entergy Utility Holding Company. As of December 31, 2021, Entergy Utility Holding Company's membership interests are held by:

Entergy Corporation 3.5% 386,954 shares
Entergy Utility Affiliates 22.2% multiple securities
Entergy Utility Assets 29.7% 3,276,704 shares
Entergy Utility Enterprises 12.5% 1,381,535 shares
Entergy Utility Group 3.2% 350,173 shares
Entergy Utility Property 27.2% 3,006,086 shares
Unaffiliated third parties 1.7% multiple securities


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
CORPORATIONS CONTROLLED BY RESPONDENT
  1. Report below the names of all corporations, business trusts, and similar organizations, controlled directly or indirectly by respondent at any time during the year. If control ceased prior to end of year, give particulars (details) in a footnote.
  2. If control was by other means than a direct holding of voting rights, state in a footnote the manner in which control was held, naming any intermediaries involved.
  3. If control was held jointly with one or more other interests, state the fact in a footnote and name the other interests.
Definitions
  1. See the Uniform System of Accounts for a definition of control.
  2. Direct control is that which is exercised without interposition of an intermediary.
  3. Indirect control is that which is exercised by the interposition of an intermediary which exercises direct control.
  4. Joint control is that in which neither interest can effectively control or direct action without the consent of the other, as where the voting control is equally divided between two holders, or each party holds a veto power over the other. Joint control may exist by mutual agreement or understanding between two or more parties who together have control within the meaning of the definition of control in the Uniform System of Accounts, regardless of the relative voting rights of each party.
Line No.
NameOfCompanyControlledByRespondent
Name of Company Controlled
(a)
CompanyControlledByRespondentKindOfBusinessDescription
Kind of Business
(b)
VotingStockOwnedByRespondentPercentage
Percent Voting Stock Owned
(c)
FootnoteReferences
Footnote Ref.
(d)
1
EMI New Nuclear, LLC
100
2
Entergy Power & Light Company
100
3
The Light, Heat and Water Company of Jackson, Mississippi
100
4
Jackson Gas Light Company
100
5
Mississippi Power & Light Company
100


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
OFFICERS
  1. Report below the name, title and salary for each executive officer whose salary is $50,000 or more. An "executive officer" of a respondent includes its president, secretary, treasurer, and vice president in charge of a principal business unit, division or function (such as sales, administration or finance), and any other person who performs similar policy making functions.
  2. If a change was made during the year in the incumbent of any position, show name and total remuneration of the previous incumbent, and the date the change in incumbency was made.
Line No.
OfficerTitle
Title
(a)
OfficerName
Name of Officer
(b)
OfficerSalary
Salary for Year
(c)
DateOfficerIncumbencyStarted
Date Started in Period
(d)
DateOfficerIncumbencyEnded
Date Ended in Period
(e)
1
President and Chief Executive Officer of Entergy Mississippi
Haley R. Fisackerly
396,604
2
Chief Executive Officer and Chairman of the Board of Entergy Corporation
Leo P. Denault
3
Executive Vice President and Chief Financial Officer
Andrew S. Marsh
4
Executive Vice President and Chief Operating Officer
Paul D. Hinnenkamp
5
Executive Vice President and General Counsel
Marcus V. Brown
6
Group President Utility Operations
Roderick K. West
7
Senior Vice President and Chief Accounting Officer
Kimberly A. Fontan
8
Senior Vice President and General Tax Counsel
Joseph T. Henderson
2021-08-02
9
Vice President and General Tax Counsel
Steven W. Brady
2021-08-02


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
FOOTNOTE DATA

(a) Concept: OfficerSalary
Salary not presented as individual was compensated by other System companies and not by Entergy Mississippi.
(b) Concept: OfficerSalary
Salary not presented as individual was compensated by other System companies and not by Entergy Mississippi.
(c) Concept: OfficerSalary
Salary not presented as individual was compensated by other System companies and not by Entergy Mississippi.
(d) Concept: OfficerSalary
Salary not presented as individual was compensated by other System companies and not by Entergy Mississippi.
(e) Concept: OfficerSalary
Salary not presented as individual was compensated by other System companies and not by Entergy Mississippi.
(f) Concept: OfficerSalary
Salary not presented as individual was compensated by other System companies and not by Entergy Mississippi.
(g) Concept: OfficerSalary
Salary not presented as individual was compensated by other System companies and not by Entergy Mississippi.
(h) Concept: OfficerSalary
Salary not presented as individual was compensated by other System companies and not by Entergy Mississippi.

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
DIRECTORS
  1. Report below the information called for concerning each director of the respondent who held office at any time during the year. Include in column (a), name and abbreviated titles of the directors who are officers of the respondent.
  2. Provide the principle place of business in column (b), designate members of the Executive Committee in column (c), and the Chairman of the Executive Committee in column (d).
Line No.
NameAndTitleOfDirector
Name (and Title) of Director
(a)
PrincipalBusinessAddress
Principal Business Address
(b)
MemberOfTheExecutiveCommittee
Member of the Executive Committee
(c)
ChairmanOfTheExecutiveCommittee
Chairman of the Executive Committee
(d)
1
Haley R. Fisackerly - President and Chief Executive Officer of Entergy Mississippi
308 East Pearl Street, Jackson, MS 39201
false
false
2
Andrew S. Marsh - Executive Vice President and Chief Financial Officer
639 Loyola Avenue, New Orleans, LA 70113
true
false
3
Roderick K. West - Group President Utility Operations
639 Loyola Avenue, New Orleans, LA 70113
true
false
4
Paul D. Hinnenkamp - Executive Vice President and Chief Operating Officer
639 Loyola Avenue, New Orleans, LA 70113
true
false


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
INFORMATION ON FORMULA RATES
Does the respondent have formula rates?
Yes

No
  1. Please list the Commission accepted formula rates including FERC Rate Schedule or Tariff Number and FERC proceeding (i.e. Docket No) accepting the rate(s) or changes in the accepted rate.
Line No.
RateScheduleTariffNumber
FERC Rate Schedule or Tariff Number
(a)
ProceedingDocketNumber
FERC Proceeding
(b)
1
Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Baseline Tariff
Docket No. ER13-1508
2
Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff
Docket No. ER16-2199
3
Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff
Docket No. ER18-1247
4
Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff
Docket No. ER19-747
5
Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff
Docket No. ER21-915
6
Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff
Docket No. ER21-1720
7
Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff
Docket No. ER21-1997
8
Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff
Docket No. ER21-2169
9
Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff
Docket No. ER22-489
10
Midcontinent Indepedent System Operator (MISO) FERC Electric Tariff - Fifth Revised Volume 1
Docket No. ER13-948
11
Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff
Docket No. ER14-649
12
Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff
Docket No. ER15-358
13
Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff
Docket No. ER15-1436
14
Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff
Docket No. ER16-227
15
Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff
Docket No. ER16-1322
16
Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff
Docket No. ER17-215
17
Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff
Docket No. ER17-1549
18
Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff
Docket No. ER17-1777
19
Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff
Docket No. ER17-2579
20
Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff
Docket No. ER18-1260
21
Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff
Docket No. ER18-1982
22
Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff
Docket No. ER19-652
23
Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff
Docket No. ER19-1503
24
Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff
Docket No. ER17-827
25
Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff
Docket No. ER20-1449
26
Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff
Docket No. ER20-1472
27
Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff
Docket No. ER21-200
28
Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff
Docket No. ER21-262
29
Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff
Docket No. ER21-2693


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
INFORMATION ON FORMULA RATES - FERC Rate Schedule/Tariff Number FERC Proceeding
Does the respondent file with the Commission annual (or more frequent) filings containing the inputs to the formula rate(s)?
Yes

No
  1. If yes, provide a listing of such filings as contained on the Commission's eLibrary website.
Line No.
AccessionNumber
Accession No.
(a)
DocumentDate
Document Date / Filed Date
(b)
DocketNumber
Docket No.
(c)
DescriptionOfFiling
Description
(d)
RateScheduleTariffNumber
Formula Rate FERC Rate Schedule Number or Tariff Number
(e)
1
03/15/2021
ER21-1429
(a)
Annual Informational MISO Attachment O Transmission Formula Rate Update


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
FOOTNOTE DATA

(a) Concept: DescriptionOfFiling
Pursuant to the Federal Energy Regulatory Commission’s orders in Docket Nos. EL12-35 and ER13-2379 and the Annual Update, Information Exchange, and Challenge Procedures of the Entergy Operating Companies set forth in Attachment O of the Midcontinent Independent System Operator, Inc.’s Open Access Transmission, Energy and Operating Reserve Markets Tariff, Entergy Services shall submit an annual Informational Filing on March 15 based on data for the second preceding calendar year data. The 2019 update was filed on March 15, 2021 in Docket No. ER21-1429. This Informational Filing is not a rate filing. It shows the development of the Entergy Operating Companies’ annual transmission revenue requirements for billing June 1, 2020 through May 31, 2021 through the application of data for Calendar Year 2019 under the Attachment O MISO Tariff.

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
INFORMATION ON FORMULA RATES - Formula Rate Variances
  1. If a respondent does not submit such filings then indicate in a footnote to the applicable Form 1 schedule where formula rate inputs differ from amounts reported in the Form 1.
  2. The footnote should provide a narrative description explaining how the "rate" (or billing) was derived if different from the reported amount in the Form 1.
  3. The footnote should explain amounts excluded from the ratebase or where labor or other allocation factors, operating expenses, or other items impacting formula rate inputs differ from amounts reported in Form 1 schedule amounts.
  4. Where the Commission has provided guidance on formula rate inputs, the specific proceeding should be noted in the footnote.
Line No.
PageNumberOfFormulaRateVariances
Page No(s).
(a)
ScheduleOfFormulaRateVariances
Schedule
(b)
ColumnOfFormulaRateVariances
Column
(c)
LineNumberOfFormulaRateVariances
Line No.
(d)
1
NONE


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
IMPORTANT CHANGES DURING THE QUARTER/YEAR

Give particulars (details) concerning the matters indicated below. Make the statements explicit and precise, and number them in accordance with the inquiries. Each inquiry should be answered. Enter "none," "not applicable," or "NA" where applicable. If information which answers an inquiry is given elsewhere in the report, make a reference to the schedule in which it appears.

  1. Changes in and important additions to franchise rights: Describe the actual consideration given therefore and state from whom the franchise rights were acquired. If acquired without the payment of consideration, state that fact.
  2. Acquisition of ownership in other companies by reorganization, merger, or consolidation with other companies: Give names of companies involved, particulars concerning the transactions, name of the Commission authorizing the transaction, and reference to Commission authorization.
  3. Purchase or sale of an operating unit or system: Give a brief description of the property, and of the transactions relating thereto, and reference to Commission authorization, if any was required. Give date journal entries called for by the Uniform System of Accounts were submitted to the Commission.
  4. Important leaseholds (other than leaseholds for natural gas lands) that have been acquired or given, assigned or surrendered: Give effective dates, lengths of terms, names of parties, rents, and other condition. State name of Commission authorizing lease and give reference to such authorization.
  5. Important extension or reduction of transmission or distribution system: State territory added or relinquished and date operations began or ceased and give reference to Commission authorization, if any was required. State also the approximate number of customers added or lost and approximate annual revenues of each class of service. Each natural gas company must also state major new continuing sources of gas made available to it from purchases, development, purchase contract or otherwise, giving location and approximate total gas volumes available, period of contracts, and other parties to any such arrangements, etc.
  6. Obligations incurred as a result of issuance of securities or assumption of liabilities or guarantees including issuance of short-term debt and commercial paper having a maturity of one year or less. Give reference to FERC or State Commission authorization, as appropriate, and the amount of obligation or guarantee.
  7. Changes in articles of incorporation or amendments to charter: Explain the nature and purpose of such changes or amendments.
  8. State the estimated annual effect and nature of any important wage scale changes during the year.
  9. State briefly the status of any materially important legal proceedings pending at the end of the year, and the results of any such proceedings culminated during the year.
  10. Describe briefly any materially important transactions of the respondent not disclosed elsewhere in this report in which an officer, director, security holder reported on Pages 104 or 105 of the Annual Report Form No. 1, voting trustee, associated company or known associate of any of these persons was a party or in which any such person had a material interest.
  11. (Reserved.)
  12. If the important changes during the year relating to the respondent company appearing in the annual report to stockholders are applicable in every respect and furnish the data required by Instructions 1 to 11 above, such notes may be included on this page.
  13. Describe fully any changes in officers, directors, major security holders and voting powers of the respondent that may have occurred during the reporting period.
  14. In the event that the respondent participates in a cash management program(s) and its proprietary capital ratio is less than 30 percent please describe the significant events or transactions causing the proprietary capital ratio to be less than 30 percent, and the extent to which the respondent has amounts loaned or money advanced to its parent, subsidiary, or affiliated companies through a cash management program(s). Additionally, please describe plans, if any to regain at least a 30 percent proprietary ratio.
1.None
2. None
3. None
4. None
5. None
6. See Entergy Mississippi's 2021 FERC Form 1 Notes to Financial Statements, Notes 4, 5, and 8.
7. None
8. Transmission, distribution, and utility support employees are represented by the International Brotherhood of Electrical Workers AFL-CIO, Local Unions 605 and 985. The Company and the Union agreed to a contract effective October 16, 2019 through October 15, 2022. Effective October 15, 2021, the wage increase was 2.0%.

Fossil operating employees are represented by the International Brotherhood of Electrical Workers AFL-CIO, Local Unions 605 and 985. The Company and the Union agreed to a contract effective April 15, 2019 through April 15, 2022. Effective April 15, 2021, the wage increase was 2.0%.

Effective April 1, 2021, executive and senior management, middle management, professionals, and non-represented operating, maintenance, and support staff pay increases averaged approximately 3.0%.
9. See Entergy Mississippi’s 2021 FERC Form 1 Notes to Financial Statements, Notes 2 and 8.
10. None
12. See Entergy Mississippi's 2021 FERC Form 1 Notes to Financial Statements.
13. See Entergy Mississippi’s 2021 FERC Form 1 pages 104 and 105 for Officer and Director changes that occurred in 2021.
14. Not applicable


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
COMPARATIVE BALANCE SHEET (ASSETS AND OTHER DEBITS)
Line No.
Title of Account
(a)
Ref. Page No.
(b)
Current Year End of Quarter/Year Balance
(c)
Prior Year End Balance 12/31
(d)
1
UtilityPlantAbstract
UTILITY PLANT
2
UtilityPlant
Utility Plant (101-106, 114)
200
6,616,604,360
6,086,747,735
3
ConstructionWorkInProgress
Construction Work in Progress (107)
200
95,935,092
135,177,686
4
UtilityPlantAndConstructionWorkInProgress
TOTAL Utility Plant (Enter Total of lines 2 and 3)
6,712,539,452
6,221,925,421
5
AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility
(Less) Accum. Prov. for Depr. Amort. Depl. (108, 110, 111, 115)
200
(a)
1,991,077,854
(b)
1,897,869,011
6
UtilityPlantNet
Net Utility Plant (Enter Total of line 4 less 5)
4,721,461,598
4,324,056,410
7
NuclearFuelInProcessOfRefinementConversionEnrichmentAndFabrication
Nuclear Fuel in Process of Ref., Conv., Enrich., and Fab. (120.1)
202
8
NuclearFuelMaterialsAndAssembliesStockAccountMajorOnly
Nuclear Fuel Materials and Assemblies-Stock Account (120.2)
9
NuclearFuelAssembliesInReactorMajorOnly
Nuclear Fuel Assemblies in Reactor (120.3)
10
SpentNuclearFuelMajorOnly
Spent Nuclear Fuel (120.4)
11
NuclearFuelUnderCapitalLeases
Nuclear Fuel Under Capital Leases (120.6)
12
AccumulatedProvisionForAmortizationOfNuclearFuelAssemblies
(Less) Accum. Prov. for Amort. of Nucl. Fuel Assemblies (120.5)
202
13
NuclearFuelNet
Net Nuclear Fuel (Enter Total of lines 7-11 less 12)
14
UtilityPlantAndNuclearFuelNet
Net Utility Plant (Enter Total of lines 6 and 13)
4,721,461,598
4,324,056,410
15
OtherElectricPlantAdjustments
Utility Plant Adjustments (116)
16
GasStoredUndergroundNoncurrent
Gas Stored Underground - Noncurrent (117)
17
OtherPropertyAndInvestmentsAbstract
OTHER PROPERTY AND INVESTMENTS
18
NonutilityProperty
Nonutility Property (121)
5,076,754
5,076,754
19
AccumulatedProvisionForDepreciationAndAmortizationOfNonutilityProperty
(Less) Accum. Prov. for Depr. and Amort. (122)
549,813
533,518
20
InvestmentInAssociatedCompanies
Investments in Associated Companies (123)
21
InvestmentInSubsidiaryCompanies
Investment in Subsidiary Companies (123.1)
224
2,242
10,547
23
NoncurrentPortionOfAllowances
Noncurrent Portion of Allowances
228
24
OtherInvestments
Other Investments (124)
25
SinkingFunds
Sinking Funds (125)
26
DepreciationFund
Depreciation Fund (126)
27
AmortizationFundFederal
Amortization Fund - Federal (127)
28
OtherSpecialFunds
Other Special Funds (128)
48,885,707
64,634,756
29
SpecialFunds
Special Funds (Non Major Only) (129)
30
DerivativeInstrumentAssetsLongTerm
Long-Term Portion of Derivative Assets (175)
31
DerivativeInstrumentAssetsHedgesLongTerm
Long-Term Portion of Derivative Assets - Hedges (176)
32
OtherPropertyAndInvestments
TOTAL Other Property and Investments (Lines 18-21 and 23-31)
53,414,890
69,188,539
33
CurrentAndAccruedAssetsAbstract
CURRENT AND ACCRUED ASSETS
34
CashAndWorkingFunds
Cash and Working Funds (Non-major Only) (130)
35
Cash
Cash (131)
28,264
10,613
36
SpecialDeposits
Special Deposits (132-134)
1,381,940
37
WorkingFunds
Working Fund (135)
38
TemporaryCashInvestments
Temporary Cash Investments (136)
47,595,970
39
NotesReceivable
Notes Receivable (141)
40
CustomerAccountsReceivable
Customer Accounts Receivable (142)
84,047,722
105,732,155
41
OtherAccountsReceivable
Other Accounts Receivable (143)
14,608,590
11,820,518
42
AccumulatedProvisionForUncollectibleAccountsCredit
(Less) Accum. Prov. for Uncollectible Acct.-Credit (144)
7,209,104
19,526,736
43
NotesReceivableFromAssociatedCompanies
Notes Receivable from Associated Companies (145)
44
AccountsReceivableFromAssociatedCompanies
Accounts Receivable from Assoc. Companies (146)
42,993,614
2,740,230
45
FuelStock
Fuel Stock (151)
227
10,290,914
17,004,333
46
FuelStockExpensesUndistributed
Fuel Stock Expenses Undistributed (152)
227
66,020
47
Residuals
Residuals (Elec) and Extracted Products (153)
227
48
PlantMaterialsAndOperatingSupplies
Plant Materials and Operating Supplies (154)
227
66,127,931
55,560,534
49
Merchandise
Merchandise (155)
227
50
OtherMaterialsAndSupplies
Other Materials and Supplies (156)
227
51
NuclearMaterialsHeldForSale
Nuclear Materials Held for Sale (157)
202/227
52
AllowanceInventoryAndWithheld
Allowances (158.1 and 158.2)
228
20,170
46,554
53
NoncurrentPortionOfAllowances
(Less) Noncurrent Portion of Allowances
228
54
StoresExpenseUndistributed
Stores Expense Undistributed (163)
227
3,510,746
3,981,225
55
GasStoredCurrent
Gas Stored Underground - Current (164.1)
56
LiquefiedNaturalGasStoredAndHeldForProcessing
Liquefied Natural Gas Stored and Held for Processing (164.2-164.3)
57
Prepayments
Prepayments (165)
16,445,586
14,052,081
58
AdvancesForGas
Advances for Gas (166-167)
59
InterestAndDividendsReceivable
Interest and Dividends Receivable (171)
1,317
131
60
RentsReceivable
Rents Receivable (172)
61
AccruedUtilityRevenues
Accrued Utility Revenues (173)
56,033,772
59,514,433
62
MiscellaneousCurrentAndAccruedAssets
Miscellaneous Current and Accrued Assets (174)
17,470
309,902
63
DerivativeInstrumentAssets
Derivative Instrument Assets (175)
294,549
638,258
64
DerivativeInstrumentAssetsLongTerm
(Less) Long-Term Portion of Derivative Instrument Assets (175)
65
DerivativeInstrumentAssetsHedges
Derivative Instrument Assets - Hedges (176)
66
DerivativeInstrumentAssetsHedgesLongTerm
(Less) Long-Term Portion of Derivative Instrument Assets - Hedges (176)
67
CurrentAndAccruedAssets
Total Current and Accrued Assets (Lines 34 through 66)
334,807,511
253,332,191
68
DeferredDebitsAbstract
DEFERRED DEBITS
69
UnamortizedDebtExpense
Unamortized Debt Expenses (181)
20,864,002
18,107,904
70
ExtraordinaryPropertyLosses
Extraordinary Property Losses (182.1)
230a
71
UnrecoveredPlantAndRegulatoryStudyCosts
Unrecovered Plant and Regulatory Study Costs (182.2)
230b
72
OtherRegulatoryAssets
Other Regulatory Assets (182.3)
232
457,274,699
344,331,627
73
PreliminarySurveyAndInvestigationCharges
Prelim. Survey and Investigation Charges (Electric) (183)
891,053
74,533
74
PreliminaryNaturalGasSurveyAndInvestigationChargesAndOtherPreliminarySurveyAndInvestigationCharges
Preliminary Natural Gas Survey and Investigation Charges 183.1)
75
OtherPreliminarySurveyAndInvestigationCharges
Other Preliminary Survey and Investigation Charges (183.2)
76
ClearingAccounts
Clearing Accounts (184)
182,547
380,956
77
TemporaryFacilities
Temporary Facilities (185)
78
MiscellaneousDeferredDebits
Miscellaneous Deferred Debits (186)
233
2,315,100
2,381,750
79
DeferredLossesFromDispositionOfUtilityPlant
Def. Losses from Disposition of Utility Plt. (187)
80
ResearchDevelopmentAndDemonstrationExpenditures
Research, Devel. and Demonstration Expend. (188)
352
81
UnamortizedLossOnReacquiredDebt
Unamortized Loss on Reaquired Debt (189)
12,159,775
13,516,748
82
AccumulatedDeferredIncomeTaxes
Accumulated Deferred Income Taxes (190)
234
607,243,412
604,138,349
83
UnrecoveredPurchasedGasCosts
Unrecovered Purchased Gas Costs (191)
84
DeferredDebits
Total Deferred Debits (lines 69 through 83)
1,100,930,588
982,931,867
85
AssetsAndOtherDebits
TOTAL ASSETS (lines 14-16, 32, 67, and 84)
6,210,614,587
5,629,509,007


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
FOOTNOTE DATA

(a) Concept: AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility
Includes a debit balance for removal costs of $136,760,640.
(b) Concept: AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility
Includes a debit balance for removal costs of $107,265,805.

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
COMPARATIVE BALANCE SHEET (LIABILITIES AND OTHER CREDITS)
Line No.
Title of Account
(a)
Ref. Page No.
(b)
Current Year End of Quarter/Year Balance
(c)
Prior Year End Balance 12/31
(d)
1
ProprietaryCapitalAbstract
PROPRIETARY CAPITAL
2
CommonStockIssued
Common Stock Issued (201)
250
3
PreferredStockIssued
Preferred Stock Issued (204)
250
4
CapitalStockSubscribed
Capital Stock Subscribed (202, 205)
5
StockLiabilityForConversion
Stock Liability for Conversion (203, 206)
6
PremiumOnCapitalStock
Premium on Capital Stock (207)
7
OtherPaidInCapital
Other Paid-In Capital (208-211)
253
329,266,361
329,266,361
8
InstallmentsReceivedOnCapitalStock
Installments Received on Capital Stock (212)
252
9
DiscountOnCapitalStock
(Less) Discount on Capital Stock (213)
254
10
CapitalStockExpense
(Less) Capital Stock Expense (214)
254b
11
RetainedEarnings
Retained Earnings (215, 215.1, 216)
118
1,510,306,089
1,343,471,946
12
UnappropriatedUndistributedSubsidiaryEarnings
Unappropriated Undistributed Subsidiary Earnings (216.1)
118
3,970
3,970
13
ReacquiredCapitalStock
(Less) Reaquired Capital Stock (217)
250
14
NoncorporateProprietorship
Noncorporate Proprietorship (Non-major only) (218)
15
AccumulatedOtherComprehensiveIncome
Accumulated Other Comprehensive Income (219)
122(a)(b)
16
ProprietaryCapital
Total Proprietary Capital (lines 2 through 15)
1,839,568,480
1,672,734,337
17
LongTermDebtAbstract
LONG-TERM DEBT
18
Bonds
Bonds (221)
256
2,195,000,000
1,795,000,000
19
ReacquiredBonds
(Less) Reaquired Bonds (222)
256
20
AdvancesFromAssociatedCompanies
Advances from Associated Companies (223)
256
21
OtherLongTermDebt
Other Long-Term Debt (224)
256
22
UnamortizedPremiumOnLongTermDebt
Unamortized Premium on Long-Term Debt (225)
12,719,332
10,404,637
23
UnamortizedDiscountOnLongTermDebtDebit
(Less) Unamortized Discount on Long-Term Debt-Debit (226)
6,865,924
6,719,830
24
LongTermDebt
Total Long-Term Debt (lines 18 through 23)
2,200,853,408
1,798,684,807
25
OtherNoncurrentLiabilitiesAbstract
OTHER NONCURRENT LIABILITIES
26
ObligationsUnderCapitalLeaseNoncurrent
Obligations Under Capital Leases - Noncurrent (227)
18,247,593
16,674,384
27
AccumulatedProvisionForPropertyInsurance
Accumulated Provision for Property Insurance (228.1)
33,185,707
40,850,588
28
AccumulatedProvisionForInjuriesAndDamages
Accumulated Provision for Injuries and Damages (228.2)
4,426,225
5,236,954
29
AccumulatedProvisionForPensionsAndBenefits
Accumulated Provision for Pensions and Benefits (228.3)
33,927,919
28,311,733
30
AccumulatedMiscellaneousOperatingProvisions
Accumulated Miscellaneous Operating Provisions (228.4)
416,001
416,001
31
AccumulatedProvisionForRateRefunds
Accumulated Provision for Rate Refunds (229)
32
LongTermPortionOfDerivativeInstrumentLiabilities
Long-Term Portion of Derivative Instrument Liabilities
33
LongTermPortionOfDerivativeInstrumentLiabilitiesHedges
Long-Term Portion of Derivative Instrument Liabilities - Hedges
34
AssetRetirementObligations
Asset Retirement Obligations (230)
10,314,948
9,762,395
35
OtherNoncurrentLiabilities
Total Other Noncurrent Liabilities (lines 26 through 34)
32,662,555
44,628,589
36
CurrentAndAccruedLiabilitiesAbstract
CURRENT AND ACCRUED LIABILITIES
37
NotesPayable
Notes Payable (231)
38
AccountsPayable
Accounts Payable (232)
112,999,501
117,628,516
39
NotesPayableToAssociatedCompanies
Notes Payable to Associated Companies (233)
40
AccountsPayableToAssociatedCompanies
Accounts Payable to Associated Companies (234)
42,928,967
61,726,899
41
CustomerDeposits
Customer Deposits (235)
86,166,586
86,200,023
42
TaxesAccrued
Taxes Accrued (236)
262
158,851,699
157,423,016
43
InterestAccrued
Interest Accrued (237)
19,683,085
22,789,449
44
DividendsDeclared
Dividends Declared (238)
45
MaturedLongTermDebt
Matured Long-Term Debt (239)
46
MaturedInterest
Matured Interest (240)
47
TaxCollectionsPayable
Tax Collections Payable (241)
2,299,129
1,869,025
48
MiscellaneousCurrentAndAccruedLiabilities
Miscellaneous Current and Accrued Liabilities (242)
17,055,527
16,824,713
49
ObligationsUnderCapitalLeasesCurrent
Obligations Under Capital Leases-Current (243)
7,709,028
7,381,893
50
DerivativesInstrumentLiabilities
Derivative Instrument Liabilities (244)
6,709,364
5,020,445
51
LongTermPortionOfDerivativeInstrumentLiabilities
(Less) Long-Term Portion of Derivative Instrument Liabilities
52
DerivativeInstrumentLiabilitiesHedges
Derivative Instrument Liabilities - Hedges (245)
53
LongTermPortionOfDerivativeInstrumentLiabilitiesHedges
(Less) Long-Term Portion of Derivative Instrument Liabilities-Hedges
54
CurrentAndAccruedLiabilities
Total Current and Accrued Liabilities (lines 37 through 53)
454,402,886
476,863,979
55
DeferredCreditsAbstract
DEFERRED CREDITS
56
CustomerAdvancesForConstruction
Customer Advances for Construction (252)
16,460,070
13,249,413
57
AccumulatedDeferredInvestmentTaxCredits
Accumulated Deferred Investment Tax Credits (255)
266
10,912,780
9,062,299
58
DeferredGainsFromDispositionOfUtilityPlant
Deferred Gains from Disposition of Utility Plant (256)
59
OtherDeferredCredits
Other Deferred Credits (253)
269
96,517,003
160,192,783
60
OtherRegulatoryLiabilities
Other Regulatory Liabilities (254)
278
286,875,679
254,519,520
61
UnamortizedGainOnReacquiredDebt
Unamortized Gain on Reaquired Debt (257)
62
AccumulatedDeferredIncomeTaxesAcceleratedAmortizationProperty
Accum. Deferred Income Taxes-Accel. Amort.(281)
272
63
AccumulatedDeferredIncomeTaxesOtherProperty
Accum. Deferred Income Taxes-Other Property (282)
709,519,498
661,156,573
64
AccumulatedDeferredIncomeTaxesOther
Accum. Deferred Income Taxes-Other (283)
562,842,228
538,416,707
65
DeferredCredits
Total Deferred Credits (lines 56 through 64)
1,683,127,258
1,636,597,295
66
LiabilitiesAndOtherCredits
TOTAL LIABILITIES AND STOCKHOLDER EQUITY (lines 16, 24, 35, 54 and 65)
6,210,614,587
5,629,509,007


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
STATEMENT OF INCOME

Quarterly

  1. Report in column (c) the current year to date balance. Column (c) equals the total of adding the data in column (g) plus the data in column (i) plus the data in column (k). Report in column (d) similar data for the previous year. This information is reported in the annual filing only.
  2. Enter in column (e) the balance for the reporting quarter and in column (f) the balance for the same three month period for the prior year.
  3. Report in column (g) the quarter to date amounts for electric utility function; in column (i) the quarter to date amounts for gas utility, and in column (k) the quarter to date amounts for other utility function for the current year quarter.
  4. Report in column (h) the quarter to date amounts for electric utility function; in column (j) the quarter to date amounts for gas utility, and in column (l) the quarter to date amounts for other utility function for the prior year quarter.
  5. If additional columns are needed, place them in a footnote.

Annual or Quarterly if applicable

  1. Do not report fourth quarter data in columns (e) and (f)
  2. Report amounts for accounts 412 and 413, Revenues and Expenses from Utility Plant Leased to Others, in another utility column in a similar manner to a utility department. Spread the amount(s) over Lines 2 thru 26 as appropriate. Include these amounts in columns (c) and (d) totals.
  3. Report amounts in account 414, Other Utility Operating Income, in the same manner as accounts 412 and 413 above.
  4. Use page 122 for important notes regarding the statement of income for any account thereof.
  5. Give concise explanations concerning unsettled rate proceedings where a contingency exists such that refunds of a material amount may need to be made to the utility's customers or which may result in material refund to the utility with respect to power or gas purchases. State for each year effected the gross revenues or costs to which the contingency relates and the tax effects together with an explanation of the major factors which affect the rights of the utility to retain such revenues or recover amounts paid with respect to power or gas purchases.
  6. Give concise explanations concerning significant amounts of any refunds made or received during the year resulting from settlement of any rate proceeding affecting revenues received or costs incurred for power or gas purchases, and a summary of the adjustments made to balance sheet, income, and expense accounts.
  7. If any notes appearing in the report to stockholders are applicable to the Statement of Income, such notes may be included at page 122.
  8. Enter on page 122 a concise explanation of only those changes in accounting methods made during the year which had an effect on net income, including the basis of allocations and apportionments from those used in the preceding year. Also, give the appropriate dollar effect of such changes.
  9. Explain in a footnote if the previous year's/quarter's figures are different from that reported in prior reports.
  10. If the columns are insufficient for reporting additional utility departments, supply the appropriate account titles report the information in a footnote to this schedule.
Line No.
Title of Account
(a)
(Ref.) Page No.
(b)
Total Current Year to Date Balance for Quarter/Year
(c)
Total Prior Year to Date Balance for Quarter/Year
(d)
Current 3 Months Ended - Quarterly Only - No 4th Quarter
(e)
Prior 3 Months Ended - Quarterly Only - No 4th Quarter
(f)
Electric Utility Current Year to Date (in dollars)
(g)
Electric Utility Previous Year to Date (in dollars)
(h)
Gas Utiity Current Year to Date (in dollars)
(i)
Gas Utility Previous Year to Date (in dollars)
(j)
Other Utility Current Year to Date (in dollars)
(k)
Other Utility Previous Year to Date (in dollars)
(l)
1
UtilityOperatingIncomeAbstract
UTILITY OPERATING INCOME
2
OperatingRevenues
Operating Revenues (400)
300
1,406,346,287
1,247,854,547
1,406,346,287
1,247,854,547
3
OperatingExpensesAbstract
Operating Expenses
4
OperationExpense
Operation Expenses (401)
320
697,588,741
639,715,857
697,588,741
639,715,857
5
MaintenanceExpense
Maintenance Expenses (402)
320
84,691,764
81,441,325
84,691,764
81,441,325
6
DepreciationExpense
Depreciation Expense (403)
336
202,917,586
188,961,954
202,917,586
188,961,954
7
DepreciationExpenseForAssetRetirementCosts
Depreciation Expense for Asset Retirement Costs (403.1)
336
11,486
10,153
11,486
10,153
8
AmortizationAndDepletionOfUtilityPlant
Amort. & Depl. of Utility Plant (404-405)
336
20,508,961
17,000,545
20,508,961
17,000,545
9
AmortizationOfElectricPlantAcquisitionAdjustments
Amort. of Utility Plant Acq. Adj. (406)
336
2,722,019
2,764,420
2,722,019
2,764,420
10
AmortizationOfPropertyLossesUnrecoveredPlantAndRegulatoryStudyCosts
Amort. Property Losses, Unrecov Plant and Regulatory Study Costs (407)
11
AmortizationOfConversionExpenses
Amort. of Conversion Expenses (407.2)
12
RegulatoryDebits
Regulatory Debits (407.3)
57,132,213
10,034,479
57,132,213
10,034,479
13
RegulatoryCredits
(Less) Regulatory Credits (407.4)
51,219,492
25,253,475
51,219,492
25,253,475
14
TaxesOtherThanIncomeTaxesUtilityOperatingIncome
Taxes Other Than Income Taxes (408.1)
262
111,711,558
101,524,934
111,711,558
101,524,934
15
IncomeTaxesOperatingIncome
Income Taxes - Federal (409.1)
262
3,023,595
26,215,013
3,023,595
26,215,013
16
IncomeTaxesUtilityOperatingIncomeOther
Income Taxes - Other (409.1)
262
10,812,857
8,575,529
10,812,857
8,575,529
17
ProvisionsForDeferredIncomeTaxesUtilityOperatingIncome
Provision for Deferred Income Taxes (410.1)
234, 272
316,143,266
243,696,378
316,143,266
243,696,378
18
ProvisionForDeferredIncomeTaxesCreditOperatingIncome
(Less) Provision for Deferred Income Taxes-Cr. (411.1)
234, 272
257,370,008
248,926,859
257,370,008
248,926,859
19
InvestmentTaxCreditAdjustments
Investment Tax Credit Adj. - Net (411.4)
266
1,836,307
554,085
1,836,307
554,085
20
GainsFromDispositionOfPlant
(Less) Gains from Disp. of Utility Plant (411.6)
21
LossesFromDispositionOfServiceCompanyPlant
Losses from Disp. of Utility Plant (411.7)
22
GainsFromDispositionOfAllowances
(Less) Gains from Disposition of Allowances (411.8)
23
LossesFromDispositionOfAllowances
Losses from Disposition of Allowances (411.9)
24
AccretionExpense
Accretion Expense (411.10)
552,553
536,902
552,553
536,902
25
UtilityOperatingExpenses
TOTAL Utility Operating Expenses (Enter Total of lines 4 thru 24)
1,173,390,502
1,045,743,070
1,173,390,502
1,045,743,070
27
NetUtilityOperatingIncome
Net Util Oper Inc (Enter Tot line 2 less 25)
232,955,785
202,111,477
232,955,785
202,111,477
28
OtherIncomeAndDeductionsAbstract
Other Income and Deductions
29
OtherIncomeAbstract
Other Income
30
NonutilityOperatingIncomeAbstract
Nonutilty Operating Income
31
RevenuesFromMerchandisingJobbingAndContractWork
Revenues From Merchandising, Jobbing and Contract Work (415)
32
CostsAndExpensesOfMerchandisingJobbingAndContractWork
(Less) Costs and Exp. of Merchandising, Job. & Contract Work (416)
33
RevenuesFromNonutilityOperations
Revenues From Nonutility Operations (417)
34
ExpensesOfNonutilityOperations
(Less) Expenses of Nonutility Operations (417.1)
16,296
16,296
35
NonoperatingRentalIncome
Nonoperating Rental Income (418)
36
EquityInEarningsOfSubsidiaryCompanies
Equity in Earnings of Subsidiary Companies (418.1)
119
405
37
InterestAndDividendIncome
Interest and Dividend Income (419)
53,379
271,577
38
AllowanceForOtherFundsUsedDuringConstruction
Allowance for Other Funds Used During Construction (419.1)
8,101,351
6,725,874
39
MiscellaneousNonoperatingIncome
Miscellaneous Nonoperating Income (421)
1,126,249
110,661
40
GainOnDispositionOfProperty
Gain on Disposition of Property (421.1)
95,187
4,158
41
OtherIncome
TOTAL Other Income (Enter Total of lines 31 thru 40)
9,359,870
7,095,569
42
OtherIncomeDeductionsAbstract
Other Income Deductions
43
LossOnDispositionOfProperty
Loss on Disposition of Property (421.2)
43,618
44
MiscellaneousAmortization
Miscellaneous Amortization (425)
45
Donations
Donations (426.1)
1,651,277
828,456
46
LifeInsurance
Life Insurance (426.2)
47
Penalties
Penalties (426.3)
8,618
104,839
48
ExpendituresForCertainCivicPoliticalAndRelatedActivities
Exp. for Certain Civic, Political & Related Activities (426.4)
2,596,819
2,258,385
49
OtherDeductions
Other Deductions (426.5)
940,946
1,082,385
50
OtherIncomeDeductions
TOTAL Other Income Deductions (Total of lines 43 thru 49)
5,224,042
4,274,065
51
TaxesApplicableToOtherIncomeAndDeductionsAbstract
Taxes Applic. to Other Income and Deductions
52
TaxesOtherThanIncomeTaxesOtherIncomeAndDeductions
Taxes Other Than Income Taxes (408.2)
262
53
IncomeTaxesFederal
Income Taxes-Federal (409.2)
262
1,559,370
1,612,355
54
IncomeTaxesOther
Income Taxes-Other (409.2)
262
390,820
404,099
55
ProvisionForDeferredIncomeTaxesOtherIncomeAndDeductions
Provision for Deferred Inc. Taxes (410.2)
234, 272
56
ProvisionForDeferredIncomeTaxesCreditOtherIncomeAndDeductions
(Less) Provision for Deferred Income Taxes-Cr. (411.2)
234, 272
57
InvestmentTaxCreditAdjustmentsNonutilityOperations
Investment Tax Credit Adj.-Net (411.5)
58
InvestmentTaxCredits
(Less) Investment Tax Credits (420)
59
TaxesOnOtherIncomeAndDeductions
TOTAL Taxes on Other Income and Deductions (Total of lines 52-58)
1,950,190
2,016,454
60
NetOtherIncomeAndDeductions
Net Other Income and Deductions (Total of lines 41, 50, 59)
6,086,018
4,837,958
61
InterestChargesAbstract
Interest Charges
62
InterestOnLongTermDebt
Interest on Long-Term Debt (427)
71,242,944
62,655,583
63
AmortizationOfDebtDiscountAndExpense
Amort. of Debt Disc. and Expense (428)
1,567,681
1,428,230
64
AmortizationOfLossOnReacquiredDebt
Amortization of Loss on Reaquired Debt (428.1)
1,356,973
1,356,973
65
AmortizationOfPremiumOnDebtCredit
(Less) Amort. of Premium on Debt-Credit (429)
439,305
366,146
66
AmortizationOfGainOnReacquiredDebtCredit
(Less) Amortization of Gain on Reaquired Debt-Credit (429.1)
67
InterestOnDebtToAssociatedCompanies
Interest on Debt to Assoc. Companies (430)
6,515
35,280
68
OtherInterestExpense
Other Interest Expense (431)
1,888,738
4,034,750
69
AllowanceForBorrowedFundsUsedDuringConstructionCredit
(Less) Allowance for Borrowed Funds Used During Construction-Cr. (432)
3,415,886
2,778,310
70
NetInterestCharges
Net Interest Charges (Total of lines 62 thru 69)
72,207,660
66,366,360
71
IncomeBeforeExtraordinaryItems
Income Before Extraordinary Items (Total of lines 27, 60 and 70)
166,834,143
140,583,075
72
ExtraordinaryItemsAbstract
Extraordinary Items
73
ExtraordinaryIncome
Extraordinary Income (434)
74
ExtraordinaryDeductions
(Less) Extraordinary Deductions (435)
75
NetExtraordinaryItems
Net Extraordinary Items (Total of line 73 less line 74)
76
IncomeTaxesExtraordinaryItems
Income Taxes-Federal and Other (409.3)
262
0
77
ExtraordinaryItemsAfterTaxes
Extraordinary Items After Taxes (line 75 less line 76)
78
NetIncomeLoss
Net Income (Total of line 71 and 77)
166,834,143
140,583,075


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report


End of:
2021
/
Q4
STATEMENT OF RETAINED EARNINGS
  1. Do not report Lines 49-53 on the quarterly report.
  2. Report all changes in appropriated retained earnings, unappropriated retained earnings, and unappropriated undistributed subsidiary earnings for the year.
  3. Each credit and debit during the year should be identified as to the retained earnings account in which recorded (Accounts 433, 436-439 inclusive). Show the contra primary account affected in column (b).
  4. State the purpose and amount for each reservation or appropriation of retained earnings.
  5. List first Account 439, Adjustments to Retained Earnings, reflecting adjustments to the opening balance of retained earnings. Follow by credit, then debit items, in that order.
  6. Show dividends for each class and series of capital stock.
  7. Show separately the State and Federal income tax effect of items shown for Account 439, Adjustments to Retained Earnings.
  8. Explain in a footnote the basis for determining the amount reserved or appropriated. If such reservation or appropriation is to be recurrent, state the number and annual amounts to be reserved or appropriated as well as the totals eventually to be accumulated.
  9. If any notes appearing in the report to stockholders are applicable to this statement, attach them at page 122.
Line No.
Item
(a)
Contra Primary Account Affected
(b)
Current Quarter/Year Year to Date Balance
(c)
Previous Quarter/Year Year to Date Balance
(d)
UnappropriatedRetainedEarningsAbstract
UNAPPROPRIATED RETAINED EARNINGS (Account 216)
1
UnappropriatedRetainedEarnings
Balance-Beginning of Period
1,343,471,946
1,212,888,466
2
ChangesAbstract
Changes
3
AdjustmentsToRetainedEarningsAbstract
Adjustments to Retained Earnings (Account 439)
4
AdjustmentsToRetainedEarningsCreditAbstract
Adjustments to Retained Earnings Credit
9
AdjustmentsToRetainedEarningsCredit
TOTAL Credits to Retained Earnings (Acct. 439)
10
AdjustmentsToRetainedEarningsDebitAbstract
Adjustments to Retained Earnings Debit
15
AdjustmentsToRetainedEarningsDebit
TOTAL Debits to Retained Earnings (Acct. 439)
16
BalanceTransferredFromIncome
Balance Transferred from Income (Account 433 less Account 418.1)
166,834,143
140,583,480
17
AppropriationsOfRetainedEarningsAbstract
Appropriations of Retained Earnings (Acct. 436)
22
AppropriationsOfRetainedEarnings
TOTAL Appropriations of Retained Earnings (Acct. 436)
23
DividendsDeclaredPreferredStockAbstract
Dividends Declared-Preferred Stock (Account 437)
29
DividendsDeclaredPreferredStock
TOTAL Dividends Declared-Preferred Stock (Acct. 437)
30
DividendsDeclaredCommonStockAbstract
Dividends Declared-Common Stock (Account 438)
30.1
DividendsDeclaredCommonStock
Common equity distributions
10,000,000
36
DividendsDeclaredCommonStock
TOTAL Dividends Declared-Common Stock (Acct. 438)
10,000,000
37
TransfersFromUnappropriatedUndistributedSubsidiaryEarnings
Transfers from Acct 216.1, Unapprop. Undistrib. Subsidiary Earnings
38
UnappropriatedRetainedEarnings
Balance - End of Period (Total 1,9,15,16,22,29,36,37)
1,510,306,089
1,343,471,946
39
AppropriatedRetainedEarningsAbstract
APPROPRIATED RETAINED EARNINGS (Account 215)
45
AppropriatedRetainedEarnings
TOTAL Appropriated Retained Earnings (Account 215)
AppropriatedRetainedEarningsAmortizationReserveFederalAbstract
APPROP. RETAINED EARNINGS - AMORT. Reserve, Federal (Account 215.1)
46
AppropriatedRetainedEarningsAmortizationReserveFederal
TOTAL Approp. Retained Earnings-Amort. Reserve, Federal (Acct. 215.1)
47
AppropriatedRetainedEarningsIncludingReserveAmortization
TOTAL Approp. Retained Earnings (Acct. 215, 215.1) (Total 45,46)
48
RetainedEarnings
TOTAL Retained Earnings (Acct. 215, 215.1, 216) (Total 38, 47) (216.1)
1,510,306,089
1,343,471,946
UnappropriatedUndistributedSubsidiaryEarningsAbstract
UNAPPROPRIATED UNDISTRIBUTED SUBSIDIARY EARNINGS (Account Report only on an Annual Basis, no Quarterly)
49
UnappropriatedUndistributedSubsidiaryEarnings
Balance-Beginning of Year (Debit or Credit)
3,970
3,565
50
EquityInEarningsOfSubsidiaryCompanies
Equity in Earnings for Year (Credit) (Account 418.1)
405
51
DividendsReceived
(Less) Dividends Received (Debit)
52
ChangesUnappropriatedUndistributedSubsidiaryEarningsCredits
TOTAL other Changes in unappropriated undistributed subsidiary earnings for the year
53
UnappropriatedUndistributedSubsidiaryEarnings
Balance-End of Year (Total lines 49 thru 52)
3,970
3,970


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
STATEMENT OF CASH FLOWS
  1. Codes to be used:(a) Net Proceeds or Payments;(b)Bonds, debentures and other long-term debt; (c) Include commercial paper; and (d) Identify separately such items as investments, fixed assets, intangibles, etc.
  2. Information about noncash investing and financing activities must be provided in the Notes to the Financial statements. Also provide a reconciliation between "Cash and Cash Equivalents at End of Period" with related amounts on the Balance Sheet.
  3. Operating Activities - Other: Include gains and losses pertaining to operating activities only. Gains and losses pertaining to investing and financing activities should be reported in those activities. Show in the Notes to the Financials the amounts of interest paid (net of amount capitalized) and income taxes paid.
  4. Investing Activities: Include at Other (line 31) net cash outflow to acquire other companies. Provide a reconciliation of assets acquired with liabilities assumed in the Notes to the Financial Statements. Do not include on this statement the dollar amount of leases capitalized per the USofA General Instruction 20; instead provide a reconciliation of the dollar amount of leases capitalized with the plant cost.
Line No.
Description (See Instructions No.1 for explanation of codes)
(a)
Current Year to Date Quarter/Year
(b)
Previous Year to Date Quarter/Year
(c)
1
NetCashFlowFromOperatingActivitiesAbstract
Net Cash Flow from Operating Activities
2
NetIncomeLoss
Net Income (Line 78(c) on page 117)
166,834,143
140,583,075
3
NoncashChargesCreditsToIncomeAbstract
Noncash Charges (Credits) to Income:
4
DepreciationAndDepletion
Depreciation and Depletion
226,712,605
209,273,974
5
NoncashAdjustmentsToCashFlowsFromOperatingActivities
Amortization of (Specify) (footnote details)
5.1
NoncashAdjustmentsToCashFlowsFromOperatingActivitiesDescription
Amortization of debt discount and expense and premium on debt and amortization of loss on reacquired debt
2,924,654
2,785,203
8
DeferredIncomeTaxesNet
Deferred Income Taxes (Net)
58,773,258
5,230,481
9
InvestmentTaxCreditAdjustmentsNet
Investment Tax Credit Adjustment (Net)
1,836,307
554,085
10
NetIncreaseDecreaseInReceivablesOperatingActivities
Net (Increase) Decrease in Receivables
10,262,223
1,889,965
11
NetIncreaseDecreaseInInventoryOperatingActivities
Net (Increase) Decrease in Inventory
3,317,479
3,505,677
12
NetIncreaseDecreaseInAllowancesInventoryOperatingActivities
Net (Increase) Decrease in Allowances Inventory
26,384
41,211
13
NetIncreaseDecreaseInPayablesAndAccruedExpensesOperatingActivities
Net Increase (Decrease) in Payables and Accrued Expenses
8,588,815
82,069,675
14
NetIncreaseDecreaseInOtherRegulatoryAssetsOperatingActivities
Net (Increase) Decrease in Other Regulatory Assets
112,943,072
63,006,579
15
NetIncreaseDecreaseInOtherRegulatoryLiabilitiesOperatingActivities
Net Increase (Decrease) in Other Regulatory Liabilities
32,356,159
74,400,316
16
AllowanceForOtherFundsUsedDuringConstructionOperatingActivities
(Less) Allowance for Other Funds Used During Construction
8,101,351
6,725,874
17
UndistributedEarningsFromSubsidiaryCompaniesOperatingActivities
(Less) Undistributed Earnings from Subsidiary Companies
18
OtherAdjustmentsToCashFlowsFromOperatingActivities
Other (provide details in footnote):
18.1
OtherAdjustmentsToCashFlowsFromOperatingActivitiesDescription
Other working capital
1,939,790
562,586
18.2
OtherAdjustmentsToCashFlowsFromOperatingActivitiesDescription
Other
17,749,280
20,393,756
22
NetCashFlowFromOperatingActivities
Net Cash Provided by (Used in) Operating Activities (Total of Lines 2 thru 21)
350,965,526
300,314,081
24
CashFlowsFromInvestmentActivitiesAbstract
Cash Flows from Investment Activities:
25
ConstructionAndAcquisitionOfPlantIncludingLandAbstract
Construction and Acquisition of Plant (including land):
26
GrossAdditionsToUtilityPlantLessNuclearFuelInvestingActivities
Gross Additions to Utility Plant (less nuclear fuel)
654,351,606
555,287,461
27
GrossAdditionsToNuclearFuelInvestingActivities
Gross Additions to Nuclear Fuel
28
GrossAdditionsToCommonUtilityPlantInvestingActivities
Gross Additions to Common Utility Plant
29
GrossAdditionsToNonutilityPlantInvestingActivities
Gross Additions to Nonutility Plant
30
AllowanceForOtherFundsUsedDuringConstructionInvestingActivities
(Less) Allowance for Other Funds Used During Construction
8,101,351
6,725,874
31
OtherConstructionAndAcquisitionOfPlantInvestmentActivities
Other (provide details in footnote):
31.1
OtherConstructionAndAcquisitionOfPlantInvestmentActivitiesDescription
Payment for Purchase of Assets
28,612,204
34
CashOutflowsForPlant
Cash Outflows for Plant (Total of lines 26 thru 33)
646,250,255
577,173,791
36
AcquisitionOfOtherNoncurrentAssets
Acquisition of Other Noncurrent Assets (d)
37
ProceedsFromDisposalOfNoncurrentAssets
Proceeds from Disposal of Noncurrent Assets (d)
39
InvestmentsInAndAdvancesToAssociatedAndSubsidiaryCompanies
Investments in and Advances to Assoc. and Subsidiary Companies
2,000
40
ContributionsAndAdvancesFromAssociatedAndSubsidiaryCompanies
Contributions and Advances from Assoc. and Subsidiary Companies
41
DispositionOfInvestmentsInAndAdvancesToAssociatedAndSubsidiaryCompaniesAbstract
Disposition of Investments in (and Advances to)
42
DispositionOfInvestmentsInAndAdvancesToAssociatedAndSubsidiaryCompanies
Disposition of Investments in (and Advances to) Associated and Subsidiary Companies
44
PurchaseOfInvestmentSecurities
Purchase of Investment Securities (a)
45
ProceedsFromSalesOfInvestmentSecurities
Proceeds from Sales of Investment Securities (a)
46
LoansMadeOrPurchased
Loans Made or Purchased
47
CollectionsOnLoans
Collections on Loans
49
NetIncreaseDecreaseInReceivablesInvestingActivities
Net (Increase) Decrease in Receivables
50
NetIncreaseDecreaseInInventoryInvestingActivities
Net (Increase) Decrease in Inventory
51
NetIncreaseDecreaseInAllowancesHeldForSpeculationInvestingActivities
Net (Increase) Decrease in Allowances Held for Speculation
52
NetIncreaseDecreaseInPayablesAndAccruedExpensesInvestingActivities
Net Increase (Decrease) in Payables and Accrued Expenses
53
OtherAdjustmentsToCashFlowsFromInvestmentActivities
Other (provide details in footnote):
53.1
OtherAdjustmentsToCashFlowsFromInvestmentActivitiesDescription
Changes in money pool receivable - net
40,456,217
44,692,410
53.2
OtherAdjustmentsToCashFlowsFromInvestmentActivitiesDescription
Other
49,048
1,719,432
57
CashFlowsProvidedFromUsedInInvestmentActivities
Net Cash Provided by (Used in) Investing Activities (Total of lines 34 thru 55)
686,659,424
530,761,949
59
CashFlowsFromFinancingActivitiesAbstract
Cash Flows from Financing Activities:
60
ProceedsFromIssuanceAbstract
Proceeds from Issuance of:
61
ProceedsFromIssuanceOfLongTermDebtFinancingActivities
Long-Term Debt (b)
398,284,127
165,385,422
62
ProceedsFromIssuanceOfPreferredStockFinancingActivities
Preferred Stock
63
ProceedsFromIssuanceOfCommonStockFinancingActivities
Common Stock
64
OtherAdjustmentsToCashFlowsFromFinancingActivities
Other (provide details in footnote):
66
NetIncreaseInShortTermDebt
Net Increase in Short-Term Debt (c)
67
OtherAdjustmentsByOutsideSourcesToCashFlowsFromFinancingActivities
Other (provide details in footnote):
70
CashProvidedByOutsideSources
Cash Provided by Outside Sources (Total 61 thru 69)
398,284,127
165,385,422
72
PaymentsForRetirementAbstract
Payments for Retirement of:
73
PaymentsForRetirementOfLongTermDebtFinancingActivities
Long-term Debt (b)
74
PaymentsForRetirementOfPreferredStockFinancingActivities
Preferred Stock
75
PaymentsForRetirementOfCommonStockFinancingActivities
Common Stock
76
OtherRetirementsOfBalancesImpactingCashFlowsFromFinancingActivities
Other (provide details in footnote):
76.1
DescriptionOfOtherRetirementsImpactingCashFlowsFromFinancingActivities
Other
1,539,205
6,964,455
76.2
DescriptionOfOtherRetirementsImpactingCashFlowsFromFinancingActivities
Changes in money pool payable - net
16,515,813
16,515,813
76.3
DescriptionOfOtherRetirementsImpactingCashFlowsFromFinancingActivities
Dividends on common equity
10,000,000
78
NetDecreaseInShortTermDebt
Net Decrease in Short-Term Debt (c)
80
DividendsOnPreferredStock
Dividends on Preferred Stock
81
DividendsOnCommonStock
Dividends on Common Stock
83
CashFlowsProvidedFromUsedInFinancingActivities
Net Cash Provided by (Used in) Financing Activities (Total of lines 70 thru 81)
383,307,519
178,865,690
85
NetIncreaseDecreaseInCashAndCashEquivalentsAbstract
Net Increase (Decrease) in Cash and Cash Equivalents
86
NetIncreaseDecreaseInCashAndCashEquivalents
Net Increase (Decrease) in Cash and Cash Equivalents (Total of line 22, 57 and 83)
47,613,621
51,582,178
88
CashAndCashEquivalents
Cash and Cash Equivalents at Beginning of Period
10,613
51,592,791
90
CashAndCashEquivalents
Cash and Cash Equivalents at End of Period
47,624,234
10,613


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
NOTES TO FINANCIAL STATEMENTS
  1. Use the space below for important notes regarding the Balance Sheet, Statement of Income for the year, Statement of Retained Earnings for the year, and Statement of Cash Flows, or any account thereof. Classify the notes according to each basic statement, providing a subheading for each statement except where a note is applicable to more than one statement.
  2. Furnish particulars (details) as to any significant contingent assets or liabilities existing at end of year, including a brief explanation of any action initiated by the Internal Revenue Service involving possible assessment of additional income taxes of material amount, or of a claim for refund of income taxes of a material amount initiated by the utility. Give also a brief explanation of any dividends in arrears on cumulative preferred stock.
  3. For Account 116, Utility Plant Adjustments, explain the origin of such amount, debits and credits during the year, and plan of disposition contemplated, giving references to Cormmission orders or other authorizations respecting classification of amounts as plant adjustments and requirements as to disposition thereof.
  4. Where Accounts 189, Unamortized Loss on Reacquired Debt, and 257, Unamortized Gain on Reacquired Debt, are not used, give an explanation, providing the rate treatment given these items. See General Instruction 17 of the Uniform System of Accounts.
  5. Give a concise explanation of any retained earnings restrictions and state the amount of retained earnings affected by such restrictions.
  6. If the notes to financial statements relating to the respondent company appearing in the annual report to the stockholders are applicable and furnish the data required by instructions above and on pages 114-121, such notes may be included herein.
  7. For the 3Q disclosures, respondent must provide in the notes sufficient disclosures so as to make the interim information not misleading. Disclosures which would substantially duplicate the disclosures contained in the most recent FERC Annual Report may be omitted.
  8. For the 3Q disclosures, the disclosures shall be provided where events subsequent to the end of the most recent year have occurred which have a material effect on the respondent. Respondent must include in the notes significant changes since the most recently completed year in such items as: accounting principles and practices; estimates inherent in the preparation of the financial statements; status of long-term contracts; capitalization including significant new borrowings or modifications of existing financing agreements; and changes resulting from business combinations or dispositions. However were material contingencies exist, the disclosure of such matters shall be provided even though a significant change since year end may not have occurred.
  9. Finally, if the notes to the financial statements relating to the respondent appearing in the annual report to the stockholders are applicable and furnish the data required by the above instructions, such notes may be included herein.
A. CASH FLOW STATEMENT, ADDITIONAL INFORMATION:
Cash and Cash Equivalents at December 31, 2021
Cash (Account 131) $28,264
Temporary Cash Investments (Account 136) 47,595,970
---------------
Total $47,624,234
=========

SUPPLEMENTAL DISCLOSURE OF CASH FLOW STATEMENT (in 000s)
Cash paid (received) during the period for:
Interest $75,745
Income Taxes ($19,673)

B. FERC FORM 1 PRESENTATION COMPARED TO GENERALLY ACCEPTED ACCOUNTING PRINCIPLES

The accompanying financial statements have been prepared in accordance with the accounting requirements of the FERC as set forth in the Uniform System of Accounts and accounting releases, which differs from GAAP. Additional comparative data, including the 2020 data for the statement of retained earnings and cash flows, are needed to present the financial position and results of operations in order to satisfy GAAP. In addition, GAAP requires the disclosure of the current and long-term portion of assets and liabilities. In accordance with FERC reporting requirements, the aforementioned disclosures were not included in these financial statements.

As required by the FERC, Entergy Mississippi classifies certain items in the income statement (primarily the classification of operating expenses and other deductions) and in the balance sheet (primarily the classification of the components of accumulated deferred income taxes, taxes accrued, certain other miscellaneous current and accrued liabilities, maturities of long-term debt, deferred debits, deferred credits, plant in service, and accumulated depreciation) in a manner different than that required by GAAP.


C. The Notes to the Financial Statements included herein are adapted from the Entergy Corporation and subsidiaries Form 10-K for the Year Ended December 31, 2021. The Form 10-K Notes to the Financial Statements are prepared in conformity with GAAP, and thus may differ in certain instances from the financial statements contained herein.

"Entergy" when used in these Notes means Entergy Corporation and its direct and indirect subsidiaries.

"Registrant Subsidiaries" when used in these Notes means Entergy Arkansas, LLC, Entergy Louisiana, LLC, Entergy Mississippi, LLC, Entergy New Orleans, LLC, Entergy Texas, Inc., and System Energy Resources, Inc.

"Utility" when used in the Notes means Entergy's business segment that generates, transmits, distributes, and sells electric power, with a small amount of natural gas distribution.

"Utility operating companies" when used in these Notes means Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas.
NOTE 1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Use of Estimates in the Preparation of Financial Statements

In conformity with generally accepted accounting principles in the United States of America, the preparation of Entergy Corporation’s consolidated financial statements and the separate financial statements of the Registrant Subsidiaries requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues, and expenses, and the disclosure of contingent assets and liabilities. Adjustments to the reported amounts of assets and liabilities may be necessary in the future to the extent that future estimates or actual results are different from the estimates used.

Property, Plant, and Equipment

Property, plant, and equipment is stated at original cost less regulatory disallowances and impairments. Depreciation is computed on the straight-line basis at rates based on the applicable estimated service lives of the various classes of property. For the Registrant Subsidiaries, the original cost of plant retired or removed, less salvage, is charged to accumulated depreciation. Normal maintenance, repairs, and minor replacement costs are charged to operating expenses. Certain combined-cycle gas turbine generating units are maintained under long-term service agreements with third-party service providers. The costs under these agreements are split between operating expenses and capital additions based upon the nature of the work performed. Substantially all of the Registrant Subsidiaries’ plant is subject to mortgage liens.

Details of property, plant, and equipment by functional category are presented on FERC Form 1 pages 204-207 and details of accumulated depreciation by functional category are presented on FERC Form 1 page 219.

Depreciation rates on average depreciable property for the Registrant Subsidiaries are shown below:
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
2021
2.7%
2.4%
3.6%
3.2%
3.2%
1.9%
2020
2.6%
2.4%
3.5%
3.1%
3.1%
2.1%
2019
2.5%
2.4%
3.2%
3.2%
3.0%
2.1%

As of December 31, 2021, construction expenditures included in accounts payable are $35.6 million for Entergy Arkansas, $507.9 million for Entergy Louisiana, $26.5 million for Entergy Mississippi, $73.1 million for Entergy Texas, and $23.4 million for System Energy. As of December 31, 2020, construction expenditures included in accounts payable are $59.7 million for Entergy Arkansas, $460.5 million for Entergy Louisiana, $31.4 million for Entergy Mississippi, $9.2 million for Entergy New Orleans, $116.8 million for Entergy Texas, and $17.7 million for System Energy.

Jointly-Owned Generating Stations

Certain Entergy subsidiaries jointly own electric generating facilities with affiliates or third parties. All parties are required to provide their own financing. The investments, fuel expenses, and other operation and maintenance expenses associated with these generating stations are recorded by the Entergy subsidiaries to the extent of their respective undivided ownership interests. As of December 31, 2021, the subsidiaries’ investment and accumulated depreciation in each of these generating stations were as follows:
Generating Stations
Fuel Type
Total Megawatt Capability (a)
Ownership
Investment
Accumulated Depreciation
(In Millions)
Utility business:
Entergy Arkansas -
Independence
Unit 1
Coal
822
31.50%
$143
$106
Independence
Common Facilities
Coal
15.75%
$43
$31
White Bluff
Units 1 and 2
Coal
1,639
57.00%
$587
$390
Ouachita (b)
Common Facilities
Gas
66.67%
$173
$156
Union (c)
Common Facilities
Gas
25.00
$29
$9
Entergy Louisiana -
Roy S. Nelson
Unit 6
Coal
521
40.25%
$294
$212
Roy S. Nelson
Unit 6 Common Facilities
Coal
19.57%
$21
$10
Big Cajun 2
Unit 3
Coal
540
24.15%
$151
$131
Big Cajun 2
Unit 3 Common Facilities
Coal
8.05%
$5
$3
Ouachita (b)
Common Facilities
Gas
33.33%
$91
$78
Acadia
Common Facilities
Gas
50.00%
$21
$2
Union (c)
Common Facilities
Gas
50.00
$59
$10
Entergy Mississippi -
Independence
Units 1 and 2 and Common Facilities
Coal
1,246
25.00%
$286
$179
Entergy New Orleans -
Union (c)
Common Facilities
Gas
25.00
$29
$8
Entergy Texas -
Roy S. Nelson
Unit 6
Coal
521
29.75%
$208
$120
Roy S. Nelson
Unit 6 Common Facilities
Coal
14.47%
$7
$3
Big Cajun 2
Unit 3
Coal
540
17.85%
$113
$84
Big Cajun 2
Unit 3 Common Facilities
Coal
5.95%
$4
$1
Montgomery County
Unit 1
Gas
909
92.44%
$728
$18
System Energy -
Grand Gulf (d)
Unit 1
Nuclear
1,404
90.00
$5,363
$3,317
a.“Total Megawatt Capability” is the dependable load carrying capability as demonstrated under actual operating conditions based on the primary fuel (assuming no curtailments) that each station was designed to utilize.
b.Ouachita Units 1 and 2 are owned 100% by Entergy Arkansas and Ouachita Unit 3 is owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the common facilities and not for the generating units.
c.Union Unit 1 is owned 100% by Entergy New Orleans, Union Unit 2 is owned 100% by Entergy Arkansas, Union Units 3 and 4 are owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the specified common facilities and not for the generating units.
d.Includes a leasehold interest held by System Energy. System Energy’s Grand Gulf lease obligations are discussed in Note 5 to the financial statements.

Allowance for Funds Used During Construction (AFUDC)

AFUDC represents the approximate net composite interest cost of borrowed funds and a reasonable return on the equity funds used for construction by the Registrant Subsidiaries. AFUDC increases both the plant balance and earnings and is realized in cash through depreciation provisions included in the rates charged to customers.

Income Taxes

Entergy Corporation and the majority of its subsidiaries file a United States consolidated federal income tax return. In September 2019, Entergy Utility Holding Company, LLC and its regulated wholly-owned subsidiaries including Entergy Arkansas, LLC, Entergy Louisiana, LLC, Entergy Mississippi, LLC, and Entergy New Orleans, LLC became eligible to join and joined the Entergy Corporation consolidated federal income tax group. These changes do not affect the accrual or allocation of income taxes for the Registrant Subsidiaries. Each tax-paying entity records income taxes as if it were a separate taxpayer and consolidating adjustments are allocated to the tax filing entities in accordance with Entergy’s intercompany income tax allocation agreements. Deferred income taxes are recorded for temporary differences between the book and tax basis of assets and liabilities, and for certain losses and credits available for carryforward.

Deferred tax assets are reduced by a valuation allowance when, in the opinion of management, it is more likely than not that some portion of the deferred tax assets will not be realized. Deferred tax assets and liabilities are adjusted for the effects of changes in tax laws and rates in the period in which the tax or rate was enacted. See the “Other Tax Matters - Tax Cuts and Jobs Act” section in Note 3 to the financial statements for discussion of the effects of the enactment of the Tax Cuts and Jobs Act in December 2017.

The benefits of investment tax credits are deferred and amortized over the average useful life of the related property, as a reduction of income tax expense, for such credits associated with rate-regulated operations in accordance with ratemaking treatment.

Accounting for the Effects of Regulation

Entergy’s Utility operating companies and System Energy are rate-regulated enterprises whose rates meet three criteria specified in accounting standards. The Utility operating companies and System Energy have rates that (i) are approved by a body (its regulator) empowered to set rates that bind customers; (ii) are cost-based; and (iii) can be charged to and collected from customers. These criteria may also be applied to separable portions of a utility’s business, such as the generation or transmission functions, or to specific classes of customers. Because the Utility operating companies and System Energy meet these criteria, each of them capitalizes costs that would otherwise be charged to expense if the rate actions of its regulator make it probable that those costs will be recovered in future revenue. Such capitalized costs are reflected as regulatory assets in the accompanying financial statements. When an enterprise concludes that recovery of a regulatory asset is no longer probable, the regulatory asset must be removed from the entity’s balance sheet.

An enterprise that ceases to meet the three criteria for all or part of its operations should report that event in its financial statements. In general, the enterprise no longer meeting the criteria should eliminate from its balance sheet all regulatory assets and liabilities related to the applicable operations. Additionally, if it is determined that a regulated enterprise is no longer recovering all of its costs, it is possible that an impairment may exist that could require further write-offs of plant assets.
Regulatory Asset or Liability for Income Taxes

Accounting standards for income taxes provide that a regulatory asset or liability be recorded if it is probable that the currently determinable future increase or decrease in regulatory income tax expense will be recovered from or returned to customers through future rates. There are two main sources of Entergy’s regulatory asset or liability for income taxes. There is a regulatory asset related to the ratemaking treatment of the tax effects of book depreciation for the equity component of AFUDC that has been capitalized to property, plant, and equipment but for which there is no corresponding tax basis. Equity-AFUDC is a component of property, plant, and equipment that is included in rate base when the plant is placed in service. There is a regulatory liability related to the adjustment of Entergy’s net deferred income taxes that was required by the enactment in December 2017 of a change in the federal corporate income tax rate, which is discussed in Note 2 and 3 to the financial statements.

Cash and Cash Equivalents

Entergy considers all unrestricted highly liquid debt instruments with an original maturity of three months or less at date of purchase to be cash equivalents.

Allowance for Doubtful Accounts

The allowance for doubtful accounts reflects Entergy’s best estimate of losses on the accounts receivable balances. The allowance is calculated as the historical rate of customer write-offs multiplied by the current accounts receivable balance, taking into account the length of time the receivable balances have been outstanding. Although the rate of customer write-offs has historically experienced minimal variation, management monitors the current condition of individual customer accounts to manage collections and ensure bad debt expense is recorded in a timely manner. Utility operating company customer accounts receivable are written off consistent with approved regulatory requirements.

Equity Method Investments

Entergy owns investments that are accounted for under the equity method of accounting because Entergy’s ownership level results in significant influence, but not control, over the investee and its operations. Entergy records its share of the investee’s comprehensive earnings and losses in income and as an increase or decrease to the investment account. Any cash distributions are charged against the investment account. Entergy discontinues the recognition of losses on equity investments when its share of losses equals or exceeds its carrying amount for an investee plus any advances made or commitments to provide additional financial support.

Derivative Financial Instruments and Commodity Derivatives

The accounting standards for derivative instruments and hedging activities require that all derivatives be recognized at fair value on the balance sheet, either as assets or liabilities, unless they meet various exceptions including the normal purchase/normal sale criteria. The changes in the fair value of recognized derivatives are recorded each period in current earnings or other comprehensive income, depending on whether a derivative is designated as part of a hedge transaction and the type of hedge transaction. Due to regulatory treatment, an offsetting regulatory asset or liability is recorded for changes in fair value of recognized derivatives for the Registrant Subsidiaries.
Contracts for commodities that will be physically delivered in quantities expected to be used or sold in the ordinary course of business, including certain purchases and sales of power and fuel, meet the normal purchase, normal sales criteria and are not recognized on the balance sheet. Revenues and expenses from these contracts are reported on a gross basis in the appropriate revenue and expense categories as the commodities are received or delivered.

For other contracts for commodities in which Entergy is hedging the variability of cash flows related to a variable-rate asset, liability, or forecasted transactions that qualify as cash flow hedges, the changes in the fair value of such derivative instruments are reported in other comprehensive income. To qualify for hedge accounting, the relationship between the hedging instrument and the hedged item must be documented to include the risk management objective and strategy and, at inception and on an ongoing basis, the effectiveness of the hedge in offsetting the changes in the cash flows of the item being hedged. Gains or losses accumulated in other comprehensive income are reclassified to earnings in the periods when the underlying transactions actually occur. Changes in the fair value of derivative instruments that are not designated as cash flow hedges are recorded in current-period earnings on a mark-to-market basis.

Fair Values

The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling. Considerable judgment is required in developing the estimates of fair value. Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments. See Note 15 to the financial statements for further discussion of fair value.

Impairment of Long-lived Assets

Entergy periodically reviews long-lived assets held in all of its business segments whenever events or changes in circumstances indicate that recoverability of these assets is uncertain. Generally, the determination of recoverability is based on the undiscounted net cash flows expected to result from such operations and assets. Projected net cash flows depend on the expected operating life of the assets, the future operating costs associated with the assets, the efficiency and availability of the assets and generating units, and the future market and price for energy and capacity over the remaining life of the assets.

Reacquired Debt

The premiums and costs associated with reacquired debt of Entergy’s Utility operating companies and System Energy (except that portion allocable to the deregulated operations of Entergy Louisiana) are included in regulatory assets and are being amortized over the life of the related new issuances, or over the life of the original debt issuance if the debt is not refinanced, in accordance with ratemaking treatment.

Taxes Imposed on Revenue-Producing Transactions

Governmental authorities assess taxes that are both imposed on and concurrent with a specific revenue-producing transaction between a seller and a customer, including, but not limited to, sales, use, value added, and some excise taxes. Entergy presents these taxes on a net basis, excluding them from revenues, unless required to report them differently by a regulatory authority.

NOTE 2. RATE AND REGULATORY MATTERS
Regulatory Assets and Regulatory Liabilities

Regulatory assets represent probable future revenues associated with costs that Entergy expects to recover from customers through the regulatory ratemaking process under which the Utility business operates. Regulatory liabilities represent probable future reductions in revenues associated with amounts that Entergy expects to benefit customers through the regulatory ratemaking process under which the Utility business operates. Details of regulatory assets in FERC account 182.3 are presented on FERC Form 1 page 232. Details of regulatory liabilities in FERC account 254 are presented on FERC Form 1 page 278.

Fuel and purchased power cost recovery

The Utility operating companies are allowed to recover fuel and purchased power costs through fuel mechanisms included in electric and gas rates that are recorded as fuel cost recovery revenues. The difference between revenues collected and the current fuel and purchased power costs is generally recorded as “Deferred fuel costs” on the Utility operating companies’ financial statements. The table below shows the amount of deferred fuel costs as of December 31, 2021 and 2020 that Entergy expects to recover (or return to customers) through fuel mechanisms, subject to subsequent regulatory review.
2021
2020
(In Millions)
Entergy Arkansas (a)
$177.6
$15.2
Entergy Louisiana (b)
$213.5
$170.4
Entergy Mississippi
$121.9
($14.7)
Entergy New Orleans (b)
($3.5)
$6.2
Entergy Texas
$48.3
($85.4)

a.Includes $68.8 million in 2021 and $68.2 million in 2020 of fuel and purchased power costs whose recovery periods are indeterminate but are expected to be recovered over a period greater than twelve months.
b.Includes $168.1 million in both years for Entergy Louisiana and $4.1 million in both years for Entergy New Orleans of fuel, purchased power, and capacity costs, which do not currently earn a return on investment and whose recovery periods are indeterminate but are expected to be recovered over a period greater than twelve months.

Entergy Mississippi

Entergy Mississippi’s rate schedules include an energy cost recovery rider that is adjusted annually to reflect accumulated over- or under-recoveries. Entergy Mississippi’s fuel cost recoveries are subject to annual audits conducted pursuant to the authority of the MPSC.

In November 2018, Entergy Mississippi filed its annual redetermination of the annual factor to be applied under the energy cost recovery rider. The calculation of the annual factor included an under-recovery of approximately $57 million as of September 30, 2018. In January 2019 the MPSC approved the proposed energy cost factor effective for February 2019 bills.

In November 2019, Entergy Mississippi filed its annual redetermination of the annual factor to be applied under the energy cost recovery rider. The calculation included $39.6 million of prior over-recovery flowing back to customers beginning February 2020. Entergy Mississippi’s balance in its deferred fuel account did not decrease as expected after implementation of the new factor. In an effort to assist customers during the
COVID-19 pandemic, in May 2020, Entergy Mississippi requested an interim adjustment to the energy cost recovery rider to credit approximately $50 million from the over-recovered balance in the deferred fuel account to customers over four consecutive billing months. The MPSC approved this interim adjustment in May 2020 effective for June through September 2020 bills.

In November 2020, Entergy Mississippi filed its annual redetermination of the annual factor to be applied under the energy cost recovery rider. The calculation of the annual factor included an over-recovery of approximately $24.4 million as of September 30, 2020. In January 2021 the MPSC approved the proposed energy cost factor effective for February 2021 bills.

In November 2021, Entergy Mississippi filed its annual redetermination of the annual factor to be applied under the energy cost recovery rider. The calculation of the annual factor included an under-recovery of approximately $80.6 million as of September 30, 2021. In December 2021, at the request of the MPSC, Entergy Mississippi submitted a proposal to mitigate the impact of rising fuel costs on customer bills during 2022. Entergy Mississippi proposed that the deferred fuel balance as of December 31, 2021, which was $121.9 million, be amortized over three years, and that the MPSC authorize Entergy Mississippi to apply its weighted-average cost of capital as the carrying cost for the unamortized fuel balance. In January 2022 the MPSC approved the amortization of $100 million of the deferred fuel balance over two years and authorized Entergy Mississippi to apply its weighted-average cost of capital as the carrying cost for the unamortized fuel balance. The MPSC approved the proposed energy cost factor effective for February 2022 bills.

Retail Rate Proceedings

Filings with the MPSC (Entergy Mississippi)

Retail Rates

Formula Rate Plan Revisions

In October 2018, Entergy Mississippi proposed revisions to its formula rate plan that would provide for a mechanism in the formula rate plan, the interim capacity rate adjustment mechanism, to recover the non-fuel related costs of additional owned capacity acquired by Entergy Mississippi, including the non-fuel annual ownership costs of the Choctaw Generating Station, as well as to allow similar cost recovery treatment for other future capacity acquisitions, such as the Sunflower Solar Facility, that are approved by the MPSC. In December 2019 the MPSC approved Entergy Mississippi’s proposed revisions to its formula rate plan to provide for an interim capacity rate adjustment mechanism to recover the $59 million first-year annual revenue requirement associated with the non-fuel ownership costs of the Choctaw Generating Station, which Entergy Mississippi began billing in January 2020. The MPSC must approve recovery through the interim capacity rate adjustment for each new resource. In addition, the MPSC approved revisions to the formula rate plan which allows Entergy Mississippi to begin billing rate adjustments effective April 1 of the filing year on a temporary basis subject to refund or credit to customers, subject to final MPSC order. The MPSC also authorized Entergy Mississippi to remove vegetation management costs from the formula rate plan and recover these costs through the establishment of a vegetation management rider. Effective with the April 2020 billing cycle, Entergy Mississippi implemented a rider to recover $22 million in vegetation management costs.

2019 Formula Rate Plan Filing

In March 2019, Entergy Mississippi submitted its formula rate plan 2019 test year filing and 2018 look-back filing showing Entergy Mississippi’s earned return for the historical 2018 calendar year to be above the
formula rate plan bandwidth and projected earned return for the 2019 calendar year to be below the formula rate plan bandwidth. The 2019 test year filing shows a $36.8 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.94% return on rate base, within the formula rate plan bandwidth. The 2018 look-back filing compares actual 2018 results to the approved benchmark return on rate base and shows a $10.1 million interim decrease in formula rate plan revenues is necessary. In the fourth quarter 2018, Entergy Mississippi recorded a provision of $9.3 million that reflected the estimate of the difference between the 2018 expected earned rate of return on rate base and an established performance-adjusted benchmark rate of return under the formula rate plan performance-adjusted bandwidth mechanism. In the first quarter 2019, Entergy Mississippi recorded a $0.8 million increase in the provision to reflect the amount shown in the look-back filing. In June 2019, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a joint stipulation that confirmed that the 2019 test year filing showed that a $32.8 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.93% return on rate base, within the formula rate plan bandwidth. Additionally, pursuant to the joint stipulation, Entergy Mississippi’s 2018 look-back filing reflected an earned return on rate base of 7.81% in calendar year 2018 which is above the look-back benchmark return on rate base of 7.13%, resulting in an $11 million decrease in formula rate plan revenues on an interim basis through May 2020. In the second quarter 2019, Entergy Mississippi recorded an additional $0.9 million increase in the provision to reflect the $11 million shown in the look-back filing. In June 2019 the MPSC approved the joint stipulation with rates effective for the first billing cycle of July 2019.

2020 Formula Rate Plan Filing

In March 2020, Entergy Mississippi submitted its formula rate plan 2020 test year filing and 2019 look-back filing showing Entergy Mississippi’s earned return for the historical 2019 calendar year to be below the formula rate plan bandwidth and projected earned return for the 2020 calendar year to be below the formula rate plan bandwidth. The 2020 test year filing shows a $24.6 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.51% return on rate base, within the formula rate plan bandwidth. The 2019 look-back filing compares actual 2019 results to the approved benchmark return on rate base and reflects the need for a $7.3 million interim increase in formula rate plan revenues. In accordance with the MPSC-approved revisions to the formula rate plan, Entergy Mississippi implemented a $24.3 million interim rate increase, reflecting a cap equal to 2% of 2019 retail revenues, effective with the April 2020 billing cycle, subject to refund. In June 2020, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a joint stipulation that confirmed that the 2020 test year filing showed that a $23.8 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.51% return on rate base, within the formula rate plan bandwidth. Pursuant to the joint stipulation, Entergy Mississippi’s 2019 look-back filing reflected an earned return on rate base of 6.75% in calendar year 2019, which is within the look-back bandwidth. As a result, there is no change in formula rate plan revenues in the 2019 look-back filing. In June 2020 the MPSC approved the joint stipulation with rates effective for the first billing cycle of July 2020. In the June 2020 order the MPSC directed Entergy Mississippi to submit revisions to its formula rate plan to realign recovery of costs from its energy efficiency cost recovery rider to its formula rate plan. In November 2020 the MPSC approved Entergy Mississippi’s revisions to its formula rate plan providing for the realignment of energy efficiency costs to its formula rate plan, the deferral of energy efficiency expenditures into a regulatory asset, and the elimination of its energy efficiency cost recovery rider effective with the January 2022 billing cycle.

2021 Formula Rate Plan Filing
In March 2021, Entergy Mississippi submitted its formula rate plan 2021 test year filing and 2020 look-back filing showing Entergy Mississippi’s earned return for the historical 2020 calendar year to be below the formula rate plan bandwidth and projected earned return for the 2021 calendar year to be below the formula rate plan bandwidth. The 2021 test year filing shows a $95.4 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.69% return on rate base, within the formula rate plan bandwidth. The change in formula rate plan revenues, however, is capped at 4% of retail revenues, which equates to a revenue change of $44.3 million. The 2021 evaluation report also includes $3.9 million in demand side management costs for which the MPSC approved realignment of recovery from the energy efficiency rider to the formula rate plan. These costs are not subject to the 4% cap and result in a total change in formula rate plan revenues of $48.2 million. The 2020 look-back filing compares actual 2020 results to the approved benchmark return on rate base and reflects the need for a $16.8 million interim increase in formula rate plan revenues. In addition, the 2020 look-back filing includes an interim capacity adjustment true-up for the Choctaw Generating Station, which increases the look-back interim rate adjustment by $1.7 million. These interim rate adjustments total $18.5 million. In accordance with the provisions of the formula rate plan, Entergy Mississippi implemented a $22.1 million interim rate increase, reflecting a cap equal to 2% of 2020 retail revenues, effective with the April 2021 billing cycle, subject to refund, pending a final MPSC order. The $3.9 million of demand side management costs and the Choctaw Generating Station true-up of $1.7 million, which are not subject to the 2% cap of 2020 retail revenues, were included in the April 2021 rate adjustments.

In June 2021, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a joint stipulation that confirmed the 2021 test year filing that resulted in a total rate increase of $48.2 million. Pursuant to the joint stipulation, Entergy Mississippi’s 2020 look-back filing reflected an earned return on rate base of 6.12% in calendar year 2020, which is below the look-back bandwidth, resulting in a $17.5 million increase in formula rate plan revenues on an interim basis through June 2022. This includes $1.7 million related to the Choctaw Generating Station and $3.7 million of COVID-19 non-bad debt expenses. See “COVID-19 Orders” below for additional discussion of provisions of the joint stipulation related to COVID-19 expenses. In June 2021 the MPSC approved the joint stipulation with rates effective for the first billing cycle of July 2021. In June 2021, Entergy Mississippi recorded regulatory credits of $19.9 million to reflect the effects of the joint stipulation.

2022 Formula Rate Plan Filing

Entergy Mississippi’s formula rate plan includes a look-back evaluation report filing in March 2022 that will compare actual 2021 results to the performance-adjusted allowed return on rate base. In fourth quarter 2021, Entergy Mississippi recorded a regulatory asset of $19 million in connection with the look-back feature of the formula rate plan to reflect that the 2021 earned return was below the formula bandwidth.

COVID-19 Orders

In March 2020 the MPSC issued an order suspending disconnections for a period of sixty days. The MPSC extended the order on disconnections through May 26, 2020. In April 2020 the MPSC issued an order authorizing utilities to defer incremental costs and expenses associated with COVID-19 compliance and to seek future recovery through rates of the prudently incurred incremental costs and expenses. In December 2020, Entergy Mississippi resumed disconnections for commercial, industrial, and governmental customers with past-due balances that have not made payment arrangements. In January 2021, Entergy Mississippi resumed disconnecting service for residential customers with past-due balances that had not made payment arrangements. Pursuant to the June 2021 MPSC order approving Entergy Mississippi’s 2021 formula rate plan filing, Entergy Mississippi stopped deferring COVID-19 non-bad debt expenses effective December 31, 2020 and included those expenses in the look-back filing for the 2021 formula rate plan test year. In the order, the MPSC also adopted
Entergy Mississippi’s quantification and methodology for calculating COVID-19 incremental bad debt expenses and authorized Entergy Mississippi to continue deferring these bad debt expenses through December 2021. As of December 31, 2021, Entergy Mississippi had a regulatory asset of $15 million for costs associated with the COVID-19 pandemic.

Entergy Arkansas Opportunity Sales Proceeding

In June 2009 the LPSC filed a complaint requesting that the FERC determine that certain of Entergy Arkansas’s sales of electric energy to third parties: (a) violated the provisions of the System Agreement that allocated the energy generated by Entergy System resources; (b) imprudently denied the Entergy System and its ultimate consumers the benefits of low-cost Entergy System generating capacity; and (c) violated the provision of the System Agreement that prohibited sales to third parties by individual companies absent an offer of a right-of-first-refusal to other Utility operating companies. The LPSC’s complaint challenged sales made beginning in 2002 and requested refunds. In July 2009 the Utility operating companies filed a response to the complaint arguing among other things that the System Agreement contemplates that the Utility operating companies may make sales to third parties for their own account, subject to the requirement that those sales be included in the load (or load shape) for the applicable Utility operating company. The FERC subsequently ordered a hearing in the proceeding.

After a hearing, the ALJ issued an initial decision in December 2010. The ALJ found that the System Agreement allowed for Entergy Arkansas to make the sales to third parties but concluded that the sales should be accounted for in the same manner as joint account sales. The ALJ concluded that “shareholders” should make refunds of the damages to the Utility operating companies, along with interest. Entergy disagreed with several aspects of the ALJ’s initial decision and in January 2011 filed with the FERC exceptions to the decision.

The FERC issued a decision in June 2012 and held that, while the System Agreement is ambiguous, it does provide authority for individual Utility operating companies to make opportunity sales for their own account and Entergy Arkansas made and priced these sales in good faith. The FERC found, however, that the System Agreement does not provide authority for an individual Utility operating company to allocate the energy associated with such opportunity sales as part of its load but provides a different allocation authority. The FERC further found that the after-the-fact accounting methodology used to allocate the energy used to supply the sales was inconsistent with the System Agreement. The FERC in its decision established further hearing procedures to quantify the effect of repricing the opportunity sales in accordance with the FERC’s June 2012 decision. The hearing was held in May 2013 and the ALJ issued an initial decision in August 2013. The LPSC, the APSC, the City Council, and FERC staff filed briefs on exceptions and/or briefs opposing exceptions. Entergy filed a brief on exceptions requesting that the FERC reverse the initial decision and a brief opposing certain exceptions taken by the LPSC and FERC staff.

In April 2016 the FERC issued orders addressing requests for rehearing filed in July 2012 and the ALJ’s August 2013 initial decision. The first order denied Entergy’s request for rehearing and affirmed the FERC’s earlier rulings that Entergy’s original methodology for allocating energy costs to the opportunity sales was incorrect and, as a result, Entergy Arkansas must make payments to the other Utility operating companies to put them in the same position that they would have been in absent the incorrect allocation. The FERC clarified that interest should be included with the payments. The second order affirmed in part, and reversed in part, the rulings in the ALJ’s August 2013 initial decision regarding the methodology that should be used to calculate the payments Entergy Arkansas is to make to the other Utility operating companies. The FERC affirmed the ALJ’s ruling that a full re-run of intra-system bills should be performed but required that methodology be modified so that the sales have the same priority for purposes of energy allocation as joint account sales. The FERC reversed the ALJ’s decision that any payments by Entergy Arkansas should be reduced by 20%. The FERC also reversed
the ALJ’s decision that adjustments to other System Agreement service schedules and excess bandwidth payments should not be taken into account when calculating the payments to be made by Entergy Arkansas. The FERC held that such adjustments and excess bandwidth payments should be taken into account but ordered further proceedings before an ALJ to address whether a cap on any reduction due to bandwidth payments was necessary and to implement the other adjustments to the calculation methodology.

In May 2016, Entergy Services filed a request for rehearing of the FERC’s April 2016 order arguing that payments made by Entergy Arkansas should be reduced as a result of the timing of the LPSC’s approval of certain contracts. Entergy Services also filed a request for clarification and/or rehearing of the FERC’s April 2016 order addressing the ALJ’s August 2013 initial decision. The APSC and the LPSC also filed requests for rehearing of the FERC’s April 2016 order. In September 2017 the FERC issued an order denying the request for rehearing on the issue of whether any payments by Entergy Arkansas to the other Utility operating companies should be reduced due to the timing of the LPSC’s approval of Entergy Arkansas’s wholesale baseload contract with Entergy Louisiana. In November 2017 the FERC issued an order denying all of the remaining requests for rehearing of the April 2016 order. In November 2017, Entergy Services filed a petition for review in the D.C. Circuit of the FERC’s orders in the first two phases of the opportunity sales case. In December 2017 the D.C. Circuit granted Entergy Services’ request to hold the appeal in abeyance pending final resolution of the related proceeding before the FERC. In January 2018 the APSC and the LPSC filed separate petitions for review in the D.C. Circuit, and the D.C. Circuit consolidated the appeals with Entergy Services’ appeal.

The hearing required by the FERC’s April 2016 order was held in May 2017. In July 2017 the ALJ issued an initial decision addressing whether a cap on any reduction due to bandwidth payments was necessary and whether to implement the other adjustments to the calculation methodology. In August 2017 the Utility operating companies, the LPSC, the APSC, and FERC staff filed individual briefs on exceptions challenging various aspects of the initial decision. In September 2017 the Utility operating companies, the LPSC, the APSC, the MPSC, the City Council, and FERC staff filed separate briefs opposing exceptions taken by various parties.

Based on testimony previously submitted in the case and its assessment of the April 2016 FERC orders, in the first quarter 2016, Entergy Arkansas recorded a liability of $87 million, which included interest, for its estimated increased costs and payment to the other Utility operating companies, and a deferred fuel regulatory asset of $75 million. Following its assessment of the course of the proceedings, including the FERC’s denial of rehearing in November 2017 described above, in the fourth quarter 2017, Entergy Arkansas recorded an additional liability of $35 million and a regulatory asset of $31 million.

In October 2018 the FERC issued an order addressing the ALJ’s July 2017 initial decision. The FERC reversed the ALJ’s decision to cap the reduction in Entergy Arkansas’s payment to account for the increased bandwidth payments that Entergy Arkansas made to the other operating companies. The FERC also reversed the ALJ’s decision that Grand Gulf sales from January through September 2000 should be included in the calculation of Entergy Arkansas’s payment. The FERC affirmed on other grounds the ALJ’s rejection of the LPSC’s claim that certain joint account sales should be accounted for as part of the calculation of Entergy Arkansas’s payment. In November 2018 the LPSC requested rehearing of the FERC’s October 2018 decision. In December 2019 the FERC denied the LPSC’s request for rehearing. In January 2020 the LPSC appealed the December 2019 decision to the D.C. Circuit.

In December 2018, Entergy made a compliance filing in response to the FERC’s October 2018 order. The compliance filing provided a final calculation of Entergy Arkansas’s payments to the other Utility operating companies, including interest. No protests were filed in response to the December 2018 compliance filing. The
December 2018 compliance filing is pending FERC action. Refunds and interest in the following amounts were paid by Entergy Arkansas to the other operating companies in December 2018:
Total refunds including interest
Payment/(Receipt)
(In Millions)
Principal
Interest
Total
Entergy Arkansas
$68
$67
$135
Entergy Louisiana
($30)
($29)
($59)
Entergy Mississippi
($18)
($18)
($36)
Entergy New Orleans
($3)
($4)
($7)
Entergy Texas
($17)
($16)
($33)

As described above, the FERC’s opportunity sales orders have been appealed to the D.C. Circuit. In February 2020 all of the appeals were consolidated and in April 2020 the D.C. Circuit established a briefing schedule. Briefing was completed in September 2020 and oral argument was heard in December 2020. In July 2021 the D.C. Circuit issued a decision denying all of the petitions for review filed in response to the FERC’s opportunity sales orders.

In February 2019 the LPSC filed a new complaint relating to two issues that were raised in the opportunity sales proceeding, but that, in its October 2018 order, the FERC held were outside the scope of the proceeding. In March 2019, Entergy Services filed an answer and motion to dismiss the new complaint. In November 2019 the FERC issued an order denying the LPSC’s complaint. The order concluded that the settlement agreement approved by the FERC in December 2015 terminating the System Agreement barred the LPSC’s new complaint. In December 2019 the LPSC requested rehearing of the FERC’s November 2019 order, and in July 2020 the FERC issued an order dismissing the LPSC’s request for rehearing. In September 2020 the LPSC appealed to the D.C. Circuit the FERC’s orders dismissing the new opportunity sales complaint. In November 2020 the D.C. Circuit issued an order establishing that briefing will occur in January 2021 through April 2021. Oral argument was held in September 2021. In December 2021 the D.C. Circuit denied the LPSC’s Petition for Review of the new opportunity sales complaint. The opportunity sales cases are complete at FERC and at the D.C. Circuit and no additional refund amounts are owed by Entergy Arkansas.

Storm Cost Recovery Filings with Retail Regulators

Entergy Mississippi

Entergy Mississippi has approval from the MPSC to collect a storm damage provision of $1.75 million per month. If Entergy Mississippi’s accumulated storm damage provision balance exceeds $15 million, the collection of the storm damage provision ceases until such time that the accumulated storm damage provision becomes less than $10 million. Entergy Mississippi’s storm damage provision balance has been less than $10 million since May 2019, and Entergy Mississippi has been billing the monthly storm damage provision since July 2019.

NOTE 3. INCOME TAXES

Details regarding income taxes are presented on FERC Form 1 pages 261-267 and 272-277.

Carryovers
The Registrant Subsidiaries’ estimated tax attributes carryovers and their expiration dates as of December 31, 2021 are as follows:
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
Federal net operating losses before 1/1/2018
$— billion
$1.7 billion
$— billion
$0.9 billion
$— billion
$— billion
Year(s) of expiration
N/A
2035-2037
N/A
2037
N/A
N/A
Federal net operating losses - 1/1/2018 forward
$4.5 billion
$4.5 billion
$2.1 billion
$0.7 billion
$2.6 billion
$— billion
Year(s) of expiration
N/A
N/A
N/A
N/A
N/A
N/A
State net operating losses
$4.8 billion
$7.2 billion
$2.3 billion
$1.7 billion
$— million
$— million
Year(s) of expiration
2023-2026
N/A
2038-2041
N/A
N/A
N/A
Misc. federal credits
$4.7 million
$12.3 million
$1.8 million
$15.3 million
$3.1 million
$1.5 million
Year(s) of expiration
2038-2041
2035-2041
2038-2041
2037-2041
2036-2041
2036-2041
State credits
$— million
$— million
$1.3 million
$—million
$2.9 million
$9 million
Year(s) of expiration
N/A
N/A
2022-2025
N/A
2027
2022-2025

As a result of the accounting for uncertain tax positions, the amount of the deferred tax assets reflected in the financial statements is less than the amount of the tax effect of the federal and state net operating loss carryovers and tax credit carryovers.

Unrecognized tax benefits

Accounting standards establish a “more-likely-than-not” recognition threshold that must be met before a tax benefit can be recognized in the financial statements. If a tax deduction is taken on a tax return but does not meet the more-likely-than-not recognition threshold, an increase in income tax liability, above what is payable on the tax return, is required to be recorded.

A reconciliation of the Registrant Subsidiaries’ beginning and ending amount of unrecognized tax benefits for 2021, 2020, and 2019 is as follows:
2021
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
(In Thousands)
Gross balance at January 1, 2021
$1,364,635
$640,295
$549,717
$639,546
$521,932
$21,652
Additions based on tax positions related to the current year
30,419
13,437
684
1,050
32,616
1,753
Additions for tax positions of prior years
15,013
9,304
1,504
6
2,315
1,897
Reductions for tax positions of prior years
(1,573)
(58,408)
(2,336)
(1,105)
(4,568)
(1,946)
Gross balance at December 31, 2021
1,408,494
604,628
549,569
639,497
552,295
23,356
Offsets to gross unrecognized tax benefits:
Loss and tax credit carryovers
(992,643)
(604,628)
(388,728)
(484,899)
(540,694)
(8,576)
Unrecognized tax benefits net of unused tax attributes and payments
$415,851
$—
$160,841
$154,598
$11,601
$14,780

2020
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
(In Thousands)
Gross balance at January 1, 2020
$1,341,242
$2,381,653
$566,287
$716,773
$21,406
$473,331
Additions based on tax positions related to the current year (a)
9,403
35,681
5,619
2,430
504,362
4,013
Additions for tax positions of prior years
13,400
10,508
1,156
294
799
4,606
Reductions for tax positions of prior years
(11,346)
(679,601)
(24,173)
(80,267)
(5,559)
(41,466)
Settlements
11,936
(1,107,946)
828
316
924
(418,832)
Gross balance at December 31, 2020
1,364,635
640,295
549,717
639,546
521,932
21,652
Offsets to gross unrecognized tax benefits:
Loss and tax credit carryovers
(1,112,628)
(640,295)
(465,679)
(451,922)
(507,720)
(7,413)
Unrecognized tax benefits net of unused tax attributes and payments
$252,007
$—
$84,038
$187,624
$14,212
$14,239

2019
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
(In Thousands)
Gross balance at January 1, 2019
$1,298,662
$2,400,171
$508,765
$686,687
$17,802
$467,487
Additions based on tax positions related to the current year
84,335
28,705
68,594
40,676
2,312
5,496
Additions for tax positions of prior years
20,399
25,090
1,651
489
1,299
2,186
Reductions for tax positions of prior years
(62,154)
(72,313)
(12,723)
(11,079)
(7)
(1,838)
Gross balance at December 31, 2019
1,341,242
2,381,653
566,287
716,773
21,406
473,331
Offsets to gross unrecognized tax benefits:
Loss and tax credit carryovers
(1,134,187)
(1,573,257)
(506,976)
(445,430)
(3,944)
(8,392)
Unrecognized tax benefits net of unused tax attributes and payments
$207,055
$808,396
$59,311
$271,343
$17,462
$464,939

a.The primary additions for Entergy Texas in 2020 are related to the mark-to-market treatment discussed in “Other Tax Matters - Tax Accounting Methods” below.

The Registrant Subsidiaries’ balances of unrecognized tax benefits included amounts which, if recognized, would have reduced income tax expense as follows:
December 31,
2021
2020
2019
(In Millions)
Entergy Arkansas
$262.1
$259.3
$203.3
Entergy Louisiana
$66.3
$63.8
$556.3
Entergy Mississippi
$51.7
$50.7
$1.9
Entergy New Orleans
$228.6
$203.5
$242.7
Entergy Texas
$2.6
$6.1
$5.7
System Energy
$1.7
$0.5
$—

Accrued balances for the possible payment of interest related to unrecognized tax benefits are as follows:

December 31,
2021
2020
2019
(In Millions)
Entergy Arkansas
$2.7
$2.3
$3.1
Entergy Louisiana
$3.7
$3.4
$14.2
Entergy Mississippi
$2.4
$1.9
$1.7
Entergy New Orleans
$5.2
$3.9
$4.7
Entergy Texas
$1.1
$0.9
$1.1
System Energy
$12.1
$11.9
$14.5

The Registrant Subsidiaries record interest and penalties related to unrecognized tax benefits in income tax expense. No penalties were recorded in 2021, 2020, and 2019. Interest (net-of-tax) was recorded as follows:

2021
2020
2019
(In Millions)
Entergy Arkansas
$0.4
($0.8)
$1.4
Entergy Louisiana
$0.3
($10.8)
($3.7)
Entergy Mississippi
$0.5
$0.2
$0.5
Entergy New Orleans
$1.3
($0.8)
$2.0
Entergy Texas
$0.2
($0.2)
$0.2
System Energy
$0.2
($2.6)
$1.3

Income Tax Audits

Entergy and its subsidiaries file U.S. federal and various state income tax returns. IRS examinations are complete for years before 2016. All state taxing authorities’ examinations are complete for years before 2014. Entergy regularly defends its positions and works with the IRS to resolve audits. The resolution of audit issues could result in significant changes to the amounts of unrecognized tax benefits in the next twelve months.

2014-2015 IRS Audit

The IRS completed its examination of the 2014 and 2015 tax years and issued its 2014-2015 RAR in November 2020. Entergy agreed to all proposed adjustments contained in the RAR. Entergy and the Registrant Subsidiaries recorded the effects of the adjustments associated with the audit in 2020.
Additional effects of the completion of the 2014-2015 IRS tax audit are discussed below within Tax Accounting Methods.

Other Tax Matters

Tax Cuts and Jobs Act (TCJA)

The most significant effect of the TCJA for Entergy and the Registrant Subsidiaries was the change in the federal corporate income tax rate from 35% to 21%, effective January 1, 2018.

TCJA also limited the deduction for net business interest expense to 30 percent of adjusted taxable income, which is similar to earnings before interest, taxes, depreciation, and amortization. The limitation does not apply to interest expense that is properly allocable to a trade or business classified as a regulated public utility. This was further modified by a temporary provision of the CARES Act resulting in an increase of the adjusted taxable income limitation from 30% to 50% for tax years that begin in 2019 or 2020.

The IRS issued final regulations which are effective for Entergy beginning with the 2021 tax year. The regulations provide that if 90% of a tax group’s consolidated assets consist of regulated utility property, the entire consolidated tax group will be treated as a regulated public utility and all of the consolidated group’s interest expense will be currently tax deductible. Entergy expects that this provision will continue to apply to Entergy’s business operations making the application of this limitation to Entergy less likely. The provision has not resulted in Entergy having to report any significant business interest expense limitations on its tax returns.

With respect to the federal corporate income tax rate change from 35% to 21% in 2017, Entergy and the Registrant Subsidiaries recorded a regulatory liability associated with the decrease in the net accumulated deferred income tax liability, which is often referred to as “excess ADIT,” a significant portion of which has been paid to customers in 2019, 2020 and 2021 in the form of lower rates. Entergy’s December 31, 2021 and December 31, 2020 balance sheets reflect a regulatory liability of $1.3 billion and $1.6 billion, respectively, as a result of the re-measurement of deferred tax assets and liabilities from the income tax rate change, amortization of excess ADIT, and payments to customers during 2019, 2020 and 2021. Entergy’s regulatory liability for income taxes includes a gross-up at the applicable tax rate because of the effect that excess ADIT has on the ratemaking formula. The regulatory liability for income taxes includes the effect of a) the reduction of the net deferred tax liability resulting in excess ADIT, and b) the tax gross-up of excess ADIT. The Registrant Subsidiaries’ December 31, 2021 and December 31, 2020 balance sheets reflect net regulatory liabilities for income taxes as follows:

2021
2020
(In Millions)
Entergy Arkansas
$432
$467
Entergy Louisiana
$338
$479
Entergy Mississippi
$212
$224
Entergy New Orleans
$42
$59
Entergy Texas
$171
$205
System Energy
$113
$152

Excess ADIT is generally classified into two categories: 1) the portion that is subject to the normalization requirements of the TCJA, i.e., “protected”, and 2) the portion that is not subject to such normalization provisions, referred to as “unprotected”. The TCJA provides that the normalization method of accounting for income taxes is required for excess ADIT associated with public utility property. The TCJA provides for the use of the average
rate assumption method (ARAM) for the determination of the timing of the return of excess ADIT associated with such property. Under ARAM, the excess ADIT is reduced over the remaining life of the asset. Remaining asset lives vary for each Registrant Subsidiary, but the average life of public utility property is typically 30 years or longer. Entergy will amortize the protected portion of the excess ADIT in conformity with the normalization requirements. The Registrant Subsidiaries’ net regulatory liability for income taxes as of December 31, 2021 and December 31, 2020, includes protected excess ADIT as follows:
2021
2020
(In Millions)
Entergy Arkansas
$463
$490
Entergy Louisiana
$669
$721
Entergy Mississippi
$237
$248
Entergy New Orleans
$56
$61
Entergy Texas
$208
$215
System Energy
$148
$173

Payment of the unprotected excess accumulated deferred income taxes results in a reduction in the regulatory liability for income taxes and a corresponding reduction in income tax expense. This has a significant effect on the effective tax rate for the period as compared to the statutory tax rate. The Registrant Subsidiaries’ net regulatory liability for income taxes as of December 31, 2021 and December 31, 2020, includes unprotected excess ADIT as follows:
2021
2020
(In Millions)
Entergy Arkansas
$12
$11
Entergy Louisiana
$148
$223
Entergy New Orleans
$—
$3
Entergy Texas
$26
$54
System Energy
$—
$16

The return of unprotected excess accumulated deferred income taxes reduced Entergy’s and the Registrant Subsidiaries’ regulatory liability for income taxes as follows for 2021 and 2020:
2021
2020
(In Millions)
Entergy
$88
$74
Entergy Arkansas
$8
$8
Entergy Louisiana
$33
$31
Entergy New Orleans
$1
$6
Entergy Texas
$28
$29
System Energy
$18
$—

In addition to the protected and unprotected excess ADIT amounts, the net regulatory liability for income taxes includes other regulatory assets and liabilities for income taxes associated with AFUDC, which is described in Note 1 to the financial statements.

Included in the effect of the computation of the changes in deferred tax assets and liabilities is the recognition threshold and measurement of uncertain tax positions resulting in unrecognized tax benefits. The
final economic outcome of such unrecognized tax benefits is generally the result of a negotiated settlement with the IRS that often differs from the amount that is recorded as realizable under GAAP. The intrinsic uncertainty with respect to all such tax positions means that the difference between current estimates of such amounts likely to be realized and actual amounts realized upon settlement may have an effect on income tax expense and the regulatory liability for income taxes in future periods.

Entergy anticipates that the effect of TCJA may continue to have ramifications that require adjustments in the future as certain events occur. These events include: 1) IRS audit adjustments to or amendments of federal and state income tax returns that include modifications to the computation of taxable income resulting from TCJA; and 2) additional guidance, interpretations, or rulings by the U.S. Department of the Treasury or the IRS. The potential exists for these types of events to result in future tax expense adjustments because of the difference in the federal corporate income tax rate between past and future periods and the effect of the tax rate change on ratemaking. In turn, these events also could potentially affect the regulatory liability for income taxes.

Coronavirus Aid, Relief, and Economic Security Act

In response to the economic impacts of the COVID-19 pandemic, President Trump signed the Coronavirus Aid, Relief, and Economic Security Act (CARES Act) into law on March 27, 2020. The CARES Act provisions that result in the most significant opportunities for tax relief to Entergy and the Registrant Subsidiaries are (i) permitting a five-year carryback of 2018-2020 NOLs, (ii) removing the 80 percent limitation on NOLs carried to tax years beginning before 2021, (iii) increasing the limitation on interest expense deductibility for 2019 and 2020, (iv) accelerating available refunds for minimum tax credit carryforwards, modifying limitations on charitable contributions during 2020, and (v) delaying the payment of employer payroll taxes. Entergy deferred approximately $64 million of 2020 payroll tax payments, payable in equal installments over two years. The initial installment of $32 million was paid in December 2021. The second installment will be paid in December 2022.

Tax Accounting Methods

In 2018, Entergy Arkansas and Entergy Mississippi accrued deductible temporary differences related to mark-to-market tax accounting for wholesale electric contracts of $2.1 billion and $1.9 billion, respectively.

Consolidated Income Tax Return of Entergy Corporation

In September 2019, Entergy Utility Holding Company, LLC and its regulated, wholly-owned subsidiaries including Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans, became eligible to and joined the Entergy Corporation consolidated federal income tax group. As a result of these four Utility operating companies re-joining the Entergy Corporation consolidated tax return group, Entergy was able to recognize a $41 million deferred tax asset associated with a previously unrecognized net operating loss carryover.

Stock Compensation

In accordance with stock compensation accounting rules, Entergy and the Registrant Subsidiaries recognized excess tax deductions as a reduction of income tax expense in the first quarter 2020. Due to the vesting and exercise of certain Entergy stock-based awards, Entergy recorded a permanent tax reduction of approximately $24.7 million, including $4.8 million for Entergy Arkansas, $8.6 million for Entergy Louisiana, $2.7 million for Entergy Mississippi, $1.5 million for Entergy New Orleans, $2.7 million for Entergy Texas, and $1.3 million for System Energy.
NOTE 4. REVOLVING CREDIT FACILITIES, LINES OF CREDIT, AND SHORT-TERM BORROWINGS

Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of December 31, 2021 as follows:
Company
Expiration Date
Amount of Facility
Interest Rate (a)
Amount Drawn as of December 31, 2021
Letters of Credit Outstanding as of December 31, 2021
Entergy Arkansas
April 2022
$25 million (b)
2.75%
Entergy Arkansas
June 2026
$150 million (c)
1.23%
Entergy Louisiana
June 2026
$350 million (c)
1.32%
$125 million
Entergy Mississippi
April 2022
$10 million (d)
1.60%
Entergy Mississippi
April 2022
$35 million (d)
1.60%
Entergy Mississippi
April 2022
$37.5 million (d)
1.60%
Entergy New Orleans
June 2024
$25 million (c)
1.73%
Entergy Texas
June 2026
$150 million (c)
1.60%
$1.3 million

a.The interest rate is the estimated interest rate as of December 31, 2021 that would have been applied to outstanding borrowings under the facility.
b.Borrowings under this Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option.
c.The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas.
d.Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option.

The commitment fees on the credit facilities range from 0.075% to 0.375% of the undrawn commitment amount for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy Texas, and of the entire facility amount for Entergy New Orleans. Each of the credit facilities requires the Registrant Subsidiary borrower to maintain a debt ratio, as defined, of 65% or less of its total capitalization. Each Registrant Subsidiary is in compliance with this covenant.

In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each entered into an uncommitted standby letter of credit facility as a means to post collateral to support its obligations to MISO. Following is a summary of the uncommitted standby letter of credit facilities as of December 31, 2021:
Company
Amount of Uncommitted Facility
Letter of Credit Fee
Letters of Credit Issued as of December 31, 2021 (a) (b)
Entergy Arkansas
$25 million
0.78%
$8.5 million
Entergy Louisiana
$125 million
0.78%
$15.0 million
Entergy Mississippi
$65 million
0.78%
$9.3 million
Entergy New Orleans
$15 million
1.00%
$1.0 million
Entergy Texas
$80 million
0.875%
$79.6 million
(a) As of December 31, 2021, letters of credit posted with MISO covered financial transmission right exposure of $0.2 million for Entergy Mississippi and $0.1 million for Entergy Texas. See Note 15 to the financial statements for discussion of financial transmission rights.
(b) As of December 31, 2021, in addition to the $9.3 million MISO letter of credit, Entergy Mississippi has $1 million of non-MISO letters of credit outstanding under this facility.

The short-term borrowings of the Registrant Subsidiaries are limited to amounts authorized by the FERC. The current FERC-authorized short-term borrowing limits for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy are effective through October 2023. In addition to borrowings from commercial banks, these companies may also borrow from the Entergy System money pool and from other internal short-term borrowing arrangements. The money pool and the other internal borrowing arrangements are inter-company borrowing arrangements designed to reduce the Utility subsidiaries’ dependence on external short-term borrowings. Borrowings from internal and external short-term borrowings combined may not exceed the FERC-authorized limits. The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of December 31, 2021 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries:
Authorized
Borrowings
(In Millions)
Entergy Arkansas
$250
$140
Entergy Louisiana
$450
$—
Entergy Mississippi
$175
$—
Entergy New Orleans
$150
$—
Entergy Texas
$200
$80
System Energy
$200
$—

NOTE 5. LONG - TERM DEBT

Details of long-term debt are presented on FERC Form 1 pages 256-257. Entergy Mississippi has obtained long-term financing authorizations from the FERC that extend through October 2023.

NOTE 6. PREFERRED EQUITY AND NONCONTROLLING INTEREST

Note 6 to the financial statements is not applicable for Entergy Mississippi.

NOTE 7. COMMON EQUITY

Note 7 to the financial statement is not applicable for Entergy Mississippi.

NOTE 8. COMMITMENTS AND CONTINGENCIES

Entergy and the Registrant Subsidiaries are involved in a number of legal, regulatory, and tax proceedings before various courts, regulatory authorities, and governmental agencies in the ordinary course of business. While management is unable to predict with certainty the outcome of such proceedings, management does not believe that the ultimate resolution of these matters will have a material adverse effect on Entergy’s results of operations, cash flows, or financial condition. Entergy discusses regulatory proceedings in Note 2 to the financial statements and discusses tax proceedings in Note 3 to the financial statements.

Property Insurance
Entergy’s nuclear owner/licensee subsidiaries are members of NEIL, a mutual insurance company that provides property damage coverage, including decontamination and reactor stabilization, to the members’ nuclear generating plants. The property damage insurance limits procured by Entergy for its Utility plants and Entergy Wholesale Commodity plants are in compliance with the financial protection requirements of the NRC.

Under the property damage and accidental outage insurance programs, all NEIL insured plants could be subject to assessments should losses exceed the accumulated funds available from NEIL. Effective April 1, 2021, the maximum amounts of such possible assessments per occurrence were as follows:
Assessments
(In Millions)
Utility:
Entergy Arkansas
$27.6
Entergy Louisiana
$49.2
Entergy Mississippi
$0.11
Entergy New Orleans
$0.11
Entergy Texas
N/A
System Energy
$21.4
In the event that one or more acts of terrorism causes property damage under one or more or all nuclear insurance policies issued by NEIL (including, but not limited to, those described above) within 12 months from the date the first property damage occurs, the maximum recovery under all such nuclear insurance policies shall be an aggregate not exceeding $3.24 billion plus the additional amounts recovered for such losses from reinsurance, indemnity, and any other sources applicable to such losses.

Non-Nuclear Property Insurance

Entergy’s non-nuclear property insurance program provides coverage on a system-wide basis for Entergy’s non-nuclear assets. The insurance program provides coverage for property damage up to $400 million per occurrence in excess of a $20 million self-insured retention except for property damage caused by the following: earthquake shock, flood, and named windstorm, including associated storm surge. For earthquake shock and flood, the insurance program provides coverage up to $400 million on an annual aggregate basis in excess of a $40 million self-insured retention. For named windstorm and associated storm surge, the insurance program provides coverage up to $125 million on an annual aggregate basis in excess of a $40 million self-insured retention. The coverage provided by the insurance program for the Entergy New Orleans gas distribution system is limited to $50 million per occurrence and is subject to the same annual aggregate limits and retentions listed above for earthquake shock, flood, and named windstorm, including associated storm surge.

Covered property generally includes power plants, substations, facilities, inventories, and gas distribution-related properties. Excluded property generally includes transmission and distribution lines, poles, and towers. For substations valued at $5 million or less, coverage for named windstorm and associated storm surge is excluded. This coverage is in place for Entergy Corporation, the Registrant Subsidiaries, and certain other Entergy subsidiaries. Entergy also purchases $400 million in terrorism insurance coverage for its conventional property. The Terrorism Risk Insurance Reauthorization Act of 2007 created a government program that provides for up to $100 billion in coverage in excess of existing coverage for a terrorist event. Under current law, the Terrorism Risk Insurance Act extends through 2027.

Employment and Labor-related Proceedings
The Registrant Subsidiaries and other Entergy subsidiaries and related entities are responding to various lawsuits in both state and federal courts and to other labor-related proceedings filed by current and former employees, recognized bargaining representatives, and certain third parties. Generally, the amount of damages being sought is not specified in these proceedings. These actions may include, but are not limited to, allegations of wrongful employment actions; wage disputes and other claims under the Fair Labor Standards Act or its state counterparts; claims of race, gender, age, and disability discrimination; disputes arising under collective bargaining agreements; unfair labor practice proceedings and other administrative proceedings before the National Labor Relations Board or concerning the National Labor Relations Act; claims of retaliation; claims of harassment and hostile work environment; and claims for or regarding benefits under various Entergy Corporation-sponsored plans. Entergy and the Registrant Subsidiaries and related entities are responding to these lawsuits and proceedings and deny liability to the claimants. Management believes that loss exposure has been and will continue to be handled so that the ultimate resolution of these matters will not be material, in the aggregate, to the financial position, results of operation, or cash flows of Entergy or the Utility operating companies.

Grand Gulf - Related Agreements

Unit Power Sales Agreement (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy)

System Energy has agreed to sell all of its share of capacity and energy from Grand Gulf to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans in accordance with specified percentages (Entergy Arkansas-36%, Entergy Louisiana-14%, Entergy Mississippi-33%, and Entergy New Orleans-17%) as ordered by the FERC. Charges under this agreement are paid in consideration for the purchasing companies’ respective entitlement to receive capacity and energy and are payable irrespective of the quantity of energy delivered. The agreement will remain in effect until terminated by the parties and the termination is approved by the FERC, most likely upon Grand Gulf’s retirement from service. In December 2016 the NRC granted the extension of Grand Gulf’s operating license to 2044. Monthly obligations are based on actual capacity and energy costs. The average monthly payments for 2021 under the agreement were approximately $16.4 million for Entergy Arkansas, $6.5 million for Entergy Louisiana, $14.6 million for Entergy Mississippi, and $7.9 million for Entergy New Orleans. See Note 2 to the financial statements for discussion of the complaints filed with the FERC against System Energy seeking a reduction in the return on equity component of the Unit Power Sales Agreement and other complaints filed with the FERC regarding the rates charged by System Energy under the System Agreement.

Availability Agreement (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy)

Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans are individually obligated to make payments or subordinated advances to System Energy in accordance with stated percentages (Entergy Arkansas-17.1%, Entergy Louisiana-26.9%, Entergy Mississippi-31.3%, and Entergy New Orleans-24.7%) in amounts that, when added to amounts received under the Unit Power Sales Agreement or otherwise, are adequate to cover all of System Energy’s operating expenses as defined, including an amount sufficient to amortize the cost of Grand Gulf 2 over 27 years (See Reallocation Agreement terms below) and expenses incurred in connection with a permanent shutdown of Grand Gulf. System Energy has assigned its rights to payments and advances to certain creditors as security for certain obligations. Since commercial operation of Grand Gulf began, payments under the Unit Power Sales Agreement have exceeded the amounts payable under the Availability Agreement. Accordingly, no payments under the Availability Agreement have ever been required. If Entergy Arkansas or Entergy Mississippi fails to make its Unit Power Sales Agreement
payments, and System Energy is unable to obtain funds from other sources, Entergy Louisiana and Entergy New Orleans could become subject to claims or demands by System Energy or its creditors for payments or advances under the Availability Agreement (or the assignments thereof) equal to the difference between their required Unit Power Sales Agreement payments and their required Availability Agreement payments.

Reallocation Agreement (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy)

System Energy, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans entered into the Reallocation Agreement relating to the sale of capacity and energy from Grand Gulf and the related costs, in which Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans agreed to assume all of Entergy Arkansas’s responsibilities and obligations with respect to Grand Gulf under the Availability Agreement. The FERC’s decision allocating a portion of Grand Gulf capacity and energy to Entergy Arkansas supersedes the Reallocation Agreement as it relates to Grand Gulf. Responsibility for any Grand Gulf 2 amortization amounts has been individually allocated (Entergy Louisiana-26.23%, Entergy Mississippi-43.97%, and Entergy New Orleans-29.80%) under the terms of the Reallocation Agreement. However, the Reallocation Agreement does not affect Entergy Arkansas’s obligation to System Energy’s lenders under the assignments referred to in the preceding paragraph. Entergy Arkansas would be liable for its share of such amounts if Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans were unable to meet their contractual obligations. No payments of any amortization amounts will be required so long as amounts paid to System Energy under the Unit Power Sales Agreement, including other funds available to System Energy, exceed amounts required under the Availability Agreement, which is expected to be the case for the foreseeable future.

NOTE 9. ASSET RETIREMENT OBLIGATIONS

Accounting standards require companies to record liabilities for all legal obligations associated with the retirement of long-lived assets that result from the normal operation of the assets. For Entergy, substantially all of its asset retirement obligations consist of its liability for decommissioning its nuclear power plants. In addition, an insignificant amount of removal costs associated with non-nuclear power plants is also included in the decommissioning and asset retirement costs line item on the balance sheets.

These liabilities are recorded at their fair values (which are the present values of the estimated future cash outflows) in the period in which they are incurred, with an accompanying addition to the recorded cost of the long-lived asset. The asset retirement obligation is accreted each year through a charge to expense, to reflect the time value of money for this present value obligation. The accretion will continue through the completion of the asset retirement activity. The amounts added to the carrying amounts of the long-lived assets will be depreciated over the useful lives of the assets. The application of accounting standards related to asset retirement obligations is earnings neutral to the rate-regulated business of the Registrant Subsidiaries.

The cumulative decommissioning and retirement cost liabilities and expenses recorded in 2021 and 2020 by the Registrant Subsidiaries were as follows:

Liabilities as of December 31, 2020


Accretion


Spending
Dispositions
Liabilities as of December 31, 2021
(In Millions)
Utility
Entergy Arkansas
1,314.2
77.7
(1.5)
1,390.4
Entergy Louisiana
1,573.3
79.9
1,653.2
Entergy Mississippi
9.8
0.5
10.3
Entergy New Orleans
3.8
0.2
4.0
Entergy Texas
8.1
0.4
8.5
System Energy
968.9
38.7
1,007.6


Liabilities as of December 31, 2019


Accretion


Spending
Liabilities as of December 31, 2020
(In Millions)
Utility
Entergy Arkansas
1,242.6
73.3
(1.7)
1,314.2
Entergy Louisiana
1,497.3
76.0
1,573.3
Entergy Mississippi
9.7
0.6
(0.5)
9.8
Entergy New Orleans
3.5
0.3
3.8
Entergy Texas
7.6
0.5
8.1
System Energy
931.7
37.2
968.9

Coal Combustion Residuals

In June 2010 the EPA issued a proposed rule on coal combustion residuals (CCRs) that contained two primary regulatory options: (1) regulating CCRs destined for disposal in landfills or received (including stored) in surface impoundments as so-called “special wastes” under the hazardous waste program of Resource Conservation and Recovery Act (RCRA) Subtitle C; or (2) regulating CCRs destined for disposal in landfills or surface impoundments as non-hazardous wastes under Subtitle D of RCRA. Under both options, CCRs that are beneficially reused in certain processes would remain excluded from hazardous waste regulation. In April 2015 the EPA published the final CCR rule with the material being regulated under the second scenario presented above - as non-hazardous wastes regulated under RCRA Subtitle D. The final regulations create new compliance requirements including modified storage, new notification and reporting practices, product disposal considerations, and CCR unit closure criteria. Entergy believes that on-site disposal options will be available at its facilities, to the extent needed for CCR that cannot be transferred for beneficial reuse. In December 2016 the Water Infrastructure Improvements for the Nation Act (WIIN Act) was signed into law, which authorizes states to regulate coal ash rather than leaving primary enforcement to citizen suit actions. States may submit to the EPA proposals for permit programs.

NOTE 10. LEASES

As of December 31, 2021 and 2020, Entergy and the Registrant Subsidiaries held operating and finance leases for fleet vehicles used in operations, real estate, and aircraft. Excluded are power purchase agreements not meeting the definition of a lease, nuclear fuel leases, and the Grand Gulf sale-leaseback which were determined not to be leases under the accounting standards.

Leases have remaining terms of one year to 59 years. Real estate leases generally include at least one five-year renewal option; however, renewal is not typically considered reasonably certain unless Entergy or a Registrant Subsidiary makes significant leasehold improvements or other modifications that would hinder its ability to easily move. In certain of the lease agreements for fleet vehicles used in operations, Entergy and the Registrant Subsidiaries provide residual value guarantees to the lessor. Due to the nature of the agreements and
Entergy’s continuing relationship with the lessor, however, Entergy and the Registrant Subsidiaries expect to renegotiate or refinance the leases prior to conclusion of the lease. As such, Entergy and the Registrant Subsidiaries do not believe it is probable that they will be required to pay anything pertaining to the residual value guarantee, and the lease liabilities and right-of-use assets are measured accordingly.

The Registrant Subsidiaries incurred the following lease costs for the year ended December 31, 2021:

Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
(In Thousands)
Operating lease cost
$15,087
$14,368
$7,018
$1,745
$5,370
Finance lease cost:
Amortization of right-of-use assets
$2,860
$3,938
$1,766
$731
$1,493
Interest on lease liabilities
$432
$607
$270
$124
$214

Of the lease costs disclosed above, Entergy Mississippi had $703 thousand in short-term lease costs for the year ended December 31, 2021.

The lease costs disclosed above materially approximate the cash flows used by the Registrant Subsidiaries for leases with all costs included within operating activities on the respective Statements of Cash Flows, except for the finance lease costs which are included in financing activities.

The Registrant Subsidiaries incurred the following lease costs for the year ended December 31, 2020:

Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
(In Thousands)
Operating lease cost
$14,344
$13,944
$6,584
$1,443
$4,870
Finance lease cost:
Amortization of right-of-use assets
$2,693
$4,097
$1,627
$712
$1,340
Interest on lease liabilities
$408
$597
$254
$120
$196

The lease costs disclosed above materially approximate the cash flows used by the Registrant Subsidiaries for leases with all costs included within operating activities on the respective Statements of Cash Flows, except for the finance lease costs which are included in financing activities.
Entergy has elected to account for short-term leases in accordance with policy options provided by accounting guidance; therefore, there are no related lease liabilities or right-of-use assets for the costs recognized above by Entergy or by its Registrant Subsidiaries in the table below.

Included within Utility Plant on the Registrant Subsidiaries’ respective balance sheets at December 31, 2021 and 2020 are the following amounts:
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
(In Thousands)
2021
Operating leases
$56,099
$46,443
$16,831
$5,480
$14,986
Finance leases
$15,043
$19,007
$9,114
$4,023
$7,583
2020
Operating leases
$55,840
$43,189
$16,538
$5,222
$14,738
Finance leases
$12,447
$16,425
$7,452
$3,428
$5,719

The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at December 31, 2021:
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
(In Thousands)
Current liabilities:
Operating leases
$12,695
$12,520
$5,866
$1,491
$4,489
Finance leases
$2,964
$4,001
$1,843
$812
$1,476
Non-current liabilities:
Operating leases
$43,420
$33,931
$10,976
$3,994
$10,505
Finance leases
$12,079
$15,006
$7,271
$3,211
$6,107

The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at December 31, 2020:
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
(In Thousands)
Current liabilities:
Operating leases
$11,942
$11,934
$5,738
$1,406
$4,277
Finance leases
$2,660
$3,821
$1,644
$686
$1,327
Non-current liabilities:
Operating leases
$43,914
$31,260
$10,867
$3,819
$10,469
Finance leases
$9,788
$12,603
$5,808
$2,741
$4,392

The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and finance leases of the Registrant Subsidiaries at December 31, 2021:

Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
Weighted average remaining lease terms:
Operating leases
5.13
4.65
5.36
5.35
3.94
Finance leases
5.89
5.57
5.63
5.94
5.97
Weighted average discount rate:
Operating leases
3.10
2.93
3.00
2.99
3.04
Finance leases
2.80
3.08
2.87
3.03
2.79

The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and finance leases of the Registrant Subsidiaries at December 31, 2020:

Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
Weighted average remaining lease terms:
Operating leases
5.74
4.72
5.30
5.78
4.30
Finance leases
5.60
5.20
5.44
5.69
5.39
Weighted average discount rate:
Operating leases
3.34
3.11
3.43
3.09
3.07
Finance leases
3.18
3.33
3.22
3.35
3.22

Maturity of the lease liabilities for the Registrant Subsidiaries as of December 31, 2021 are as follows:

Operating Leases

Year
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
(In Thousands)
2022
$14,180
$13,706
$6,280
$1,682
$4,888
2023
12,713
11,791
4,181
1,441
4,449
2024
11,150
9,618
3,174
1,182
3,427
2025
9,292
6,694
2,168
773
1,933
2026
7,314
4,081
827
398
771
Years thereafter
5,892
3,574
1,924
601
423
Minimum lease payments
60,541
49,464
18,554
6,077
15,891
Less: amount representing interest
4,425
3,013
1,711
592
898
Present value of net minimum lease payments
$56,116
$46,451
$16,843
$5,485
$14,993

Finance Leases
Year
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
(In Thousands)
2022
$3,319
$4,481
$2,054
$854
$1,637
2023
3,100
4,231
1,971
814
1,532
2024
2,791
3,671
1,783
712
1,382
2025
2,449
3,122
1,529
621
1,256
2026
2,018
2,367
1,202
545
1,016
Years thereafter
2,477
2,613
1,220
673
1,296
Minimum lease payments
16,154
20,485
9,759
4,219
8,119
Less: amount representing interest
1,111
1,478
645
196
536
Present value of net minimum lease payments
$15,043
$19,007
$9,114
$4,023
$7,583

In allocating consideration in lease contracts to the lease and non-lease components, Entergy and the Registrant Subsidiaries have made the accounting policy election to combine lease and non-lease components related to fleet vehicles used in operations, fuel storage agreements, and purchased power agreements and to allocate the contract consideration to both lease and non-lease components for real estate leases.

NOTE 11. RETIREMENT, OTHER POSTRETIREMENT BENEFITS, AND DEFINED CONTRIBUTION PLANS

Qualified Pension Plans

Entergy has eight defined benefit qualified pension plans. The Entergy Corporation Retirement Plan for Non-Bargaining Employees (Non-Bargaining Plan I), the Entergy Corporation Retirement Plan for Bargaining Employees (Bargaining Plan I), the Entergy Corporation Retirement Plan II for Non-Bargaining Employees (Non-Bargaining Plan II), the Entergy Corporation Retirement Plan II for Bargaining Employees, the Entergy Corporation Retirement Plan III, and the Entergy Corporation Retirement Plan IV for Bargaining Employees are non-contributory final average pay plans that provide pension benefits based on employees’ credited service and compensation during employment. Non-bargaining employees whose most recent date of hire is after June 30, 2014 and before January 1, 2021 do not participate in a final average pay plan, but instead participate in the Entergy Corporation Cash Balance Plan for Non-Bargaining Employees (Non-Bargaining Cash Balance Plan). Effective January 1, 2021, the Non-Bargaining Cash Balance Plan was closed to non-bargaining employees whose most recent date of hire is after December 31, 2020, who instead may be eligible to participate in, and receive a discretionary employer contribution under, the Savings Plan of Entergy Corporation and Subsidiaries VIII, an Entergy-sponsored tax-qualified defined contribution plan that includes a 401(k) feature. Certain bargaining employees whose most recent date of hire is after June 30, 2014, or such later date provided for in their applicable collective bargaining agreements, participate in the Entergy Corporation Cash Balance Plan for Bargaining Employees (Bargaining Cash Balance Plan). Effective January 1, 2021, the Bargaining Cash Balance Plan was amended to close participation in the plan to those bargaining employees whose most recent hire date is after December 31, 2020 or such later date provided for in their applicable collective bargaining agreements. The Registrant Subsidiaries participate in these four plans: Non-Bargaining Plan I, Bargaining Plan I, Non-Bargaining Cash Balance Plan, and Bargaining Cash Balance Plan. Effective January 1, 2022, the Non-Bargaining Cash Balance Plan was merged with and into Non-Bargaining Plan I.
The assets of the six final average pay defined benefit qualified pension plans are held in a master trust established by Entergy, and the assets of the two cash balance pension plans are held in a second master trust established by Entergy. Each pension plan has an undivided beneficial interest in each of the investment accounts in its respective master trust that is maintained by a trustee. Use of the master trusts permits the commingling of the trust assets of the pension plans of Entergy Corporation and its Registrant Subsidiaries for investment and administrative purposes. Although assets in the master trusts are commingled, the trustee maintains supporting records for the purpose of allocating the trust level equity in net earnings (loss) and the administrative expenses of the investment accounts in each trust to the various participating pension plans in that particular trust. The fair value of the trusts’ assets is determined by the trustee and certain investment managers. For each trust, the trustee calculates a daily earnings factor, including realized and unrealized gains or losses, collected and accrued income, and administrative expenses, and allocates earnings to each plan in the master trusts on a pro rata basis. Effective January 1, 2022, the assets of the remaining cash balance pension plan held in a second master trust were merged with and into a master trust that holds the assets of the six final average pay defined benefit qualified pension plans.

Within each pension plan, the record of each Registrant Subsidiary’s beneficial interest in the plan assets is maintained by the plan’s actuary and is updated quarterly. Assets for each Registrant Subsidiary are increased for investment net income and contributions, and are decreased for benefit payments. A plan’s investment net income/loss (i.e. interest and dividends, realized and unrealized gains and losses and expenses) is allocated to the Registrant Subsidiaries participating in that plan based on the value of assets for each Registrant Subsidiary at the beginning of the quarter adjusted for contributions and benefit payments made during the quarter.

Entergy Corporation and its subsidiaries fund pension plans in an amount not less than the minimum required contribution under the Employee Retirement Income Security Act of 1974, as amended, and the Internal Revenue Code of 1986, as amended. The assets of the plans include common and preferred stocks, fixed-income securities, interest in a money market fund, and insurance contracts. The Registrant Subsidiaries’ pension costs are recovered from customers as a component of cost of service in each of their respective jurisdictions.

Components of Qualified Net Pension Cost and Other Amounts Recognized as a Regulatory Asset and/or Accumulated Other Comprehensive Income (AOCI)

The Registrant Subsidiaries’ total 2021, 2020, and 2019 qualified pension costs and amounts recognized as a regulatory asset and/or other comprehensive income, including amounts capitalized, for their employees included the following components:
2021
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
(In Thousands)
Net periodic pension cost:
Service cost - benefits earned during the period
$28,632
$38,271
$9,070
$3,038
$6,921
$8,851
Interest cost on projected benefit obligation
35,683
39,740
10,446
4,392
8,381
9,087
Expected return on assets
(78,368)
(89,821)
(22,407)
(10,598)
(21,158)
(19,254)
Recognized net loss
69,290
67,015
20,007
7,596
12,676
18,404
Settlement charges
37,682
61,945
16,710
5,431
11,797
12,260
Net pension cost
$92,919
$117,150
$33,826
$9,859
$18,617
$29,348
Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax)
Arising this period:
Net gain
($96,066)
($89,534)
($29,675)
($16,159)
($18,217)
($27,617)
Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year:
Amortization of net loss
(69,290)
(67,015)
(20,007)
(7,596)
(12,676)
(18,404)
Settlement charge
(37,682)
(61,945)
(16,710)
(5,431)
(11,797)
(12,260)
Total
($203,038)
($218,494)
($66,392)
($29,186)
($42,690)
($58,281)
Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax)
($110,119)
($101,344)
($32,566)
($19,327)
($24,073)
($28,933)

2020
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
(In Thousands)
Net periodic pension cost:
Service cost - benefits earned during the period
$26,329
$35,158
$8,060
$2,654
$6,116
$7,883
Interest cost on projected benefit obligation
44,165
50,432
12,922
5,825
10,731
11,006
Expected return on assets
(78,187)
(89,691)
(23,147)
(10,509)
(21,951)
(18,757)
Recognized net loss
68,338
66,640
18,983
8,018
13,173
17,104
Settlement charges
21,078
8,109
3,366
4,289
105
Net pension cost
$81,723
$70,648
$20,184
$5,988
$12,358
$17,341
Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax)
Arising this period:
Net loss
$106,178
$90,064
$36,899
$8,148
$13,379
$35,403
Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year:
Amortization of net loss
(69,713)
(68,248)
(19,393)
(8,213)
(13,564)
(17,434)
Settlement charge
(21,078)
(8,109)
(3,366)
(4,289)
(105)
Total
$15,387
$13,707
$14,140
($65)
($4,474)
$17,864
Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax)
$97,110
$84,355
$34,324
$5,923
$7,884
$35,205

2019
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
(In Thousands)
Net periodic pension cost:
Service cost - benefits earned during the period
$21,043
$29,137
$6,516
$2,274
$5,401
$6,199
Interest cost on projected benefit obligation
56,701
63,529
16,272
7,495
14,451
13,456
Expected return on assets
(80,705)
(90,607)
(23,873)
(10,785)
(23,447)
(18,710)
Recognized net loss
47,361
46,571
12,416
6,117
9,335
11,400
Net pension cost
$44,400
$48,630
$11,331
$5,101
$5,740
$12,345
Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax)
Arising this period:
Net loss
$118,898
$99,346
$41,088
$6,531
$10,869
$36,711
Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year:
Amortization of net loss
(47,361)
(46,571)
(12,416)
(6,117)
(9,335)
(11,400)
Total
$71,537
$52,775
$28,672
$414
$1,534
$25,311
Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax)
$115,937
$101,405
$40,003
$5,515
$7,274
$37,656

Qualified Pension Obligations, Plan Assets, Funded Status, Amounts Recognized in the Balance Sheet

Qualified pension obligations, plan assets, funded status, amounts recognized in the Balance Sheets for the Registrant Subsidiaries as of December 31, 2021 and 2020 are as follows:
2021
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
(In Thousands)
Change in Projected Benefit Obligation (PBO)
Balance at January 1
$1,739,382
$1,927,271
$510,109
$220,287
$410,664
$441,148
Service cost
28,632
38,271
9,070
3,038
6,921
8,851
Interest cost
35,683
39,740
10,446
4,392
8,381
9,087
Actuarial gain
(41,227)
(28,439)
(14,831)
(9,118)
(3,971)
(14,746)
Benefits paid (a)
(183,124)
(240,447)
(65,936)
(23,219)
(50,193)
(49,546)
Balance at December 31
$1,579,346
$1,736,396
$448,858
$195,380
$371,802
$394,794
Change in Plan Assets
Fair value of assets at January 1
$1,285,856
$1,476,306
$371,394
$172,551
$349,748
$310,818
Actual return on plan assets
133,207
150,917
37,251
17,639
35,405
32,125
Employer contributions
66,649
59,882
13,715
5,395
6,955
18,663
Benefits paid (a)
(183,124)
(240,447)
(65,936)
(23,219)
(50,193)
(49,546)
Fair value of assets at December 31
$1,302,588
$1,446,658
$356,424
$172,366
$341,915
$312,060
Funded status
($276,758)
($289,738)
($92,434)
($23,014)
($29,887)
($82,734)
Amounts recognized in the balance sheet (funded status)
Non-current liabilities
($276,758)
($289,738)
($92,434)
($23,014)
($29,887)
($82,734)
Amounts recognized as regulatory asset
Net loss
$612,963
$556,345
$173,511
$62,805
$113,790
$153,782
Amounts recognized as AOCI (before tax)
Net loss
$—
$23,181
$—
$—
$—
$—

(a) Including settlement lump sum benefit payments of ($104.4) million at Entergy Arkansas, ($166.6) million at Entergy Louisiana, ($45.7) million at Entergy Mississippi, ($14.3) million at Entergy New Orleans, ($31.9) million at Entergy Texas, and ($33) million at System Energy.
2020
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
(In Thousands)
Change in Projected Benefit Obligation (PBO)
Balance at January 1
$1,615,084
$1,784,474
$471,510
$206,962
$396,764
$393,607
Service cost
26,329
35,158
8,060
2,654
6,116
7,883
Interest cost
44,165
50,432
12,922
5,825
10,731
11,006
Actuarial loss
196,755
196,032
62,564
20,535
37,579
57,574
Benefits paid (a)
(142,951)
(138,825)
(44,947)
(15,689)
(40,526)
(28,922)
Balance at December 31
$1,739,382
$1,927,271
$510,109
$220,287
$410,664
$441,148
Change in Plan Assets
Fair value of assets at January 1
$1,200,035
$1,364,030
$354,928
$160,777
$339,126
$282,668
Actual return on plan assets
168,764
195,658
48,812
22,896
46,151
40,927
Employer contributions
60,008
55,443
12,601
4,567
4,997
16,145
Benefits paid (a)
(142,951)
(138,825)
(44,947)
(15,689)
(40,526)
(28,922)
Fair value of assets at December 31
$1,285,856
$1,476,306
$371,394
$172,551
$349,748
$310,818
Funded status
($453,526)
($450,965)
($138,715)
($47,736)
($60,916)
($130,330)
Amounts recognized in the balance sheet (funded status)
Non-current liabilities
($453,526)
($450,965)
($138,715)
($47,736)
($60,916)
($130,330)
Amounts recognized as regulatory asset
Net loss
$816,002
$766,099
$239,904
$91,991
$156,480
$212,062
Amounts recognized as AOCI (before tax)
Net loss
$—
$31,921
$—
$—
$—
$—

(a) Including settlement lump sum benefit payments of ($48.4) million at Entergy Arkansas, ($18.6) million at Entergy Louisiana, ($7.7) million at Entergy Mississippi, ($9.8) million at Entergy Texas, and ($236) thousand at System Energy.

The qualified pension plans incurred actuarial gains during 2021 primarily due to a rise in bond yields that resulted in increases to the discount rates used to develop the benefit obligations and an actual return on assets exceeding the expected return on assets for 2021. The qualified pension plans incurred actuarial losses during 2020 primarily due to a fall in bond yields that resulted in decreases to the discount rates used to develop the benefit obligations. These losses were partially offset by gains resulting from the actual return on assets exceeding the expected return on assets for 2020.

Accumulated Pension Benefit Obligation

The qualified pension accumulated benefit obligation for each of the Registrant Subsidiaries for their employees as of December 31, 2021 and 2020 was as follows:
December 31,
2021
2020
(In Thousands)
Entergy Arkansas
$1,463,966
$1,617,858
Entergy Louisiana
$1,574,273
$1,753,980
Entergy Mississippi
$407,851
$466,497
Entergy New Orleans
$178,010
$201,159
Entergy Texas
$342,441
$379,050
System Energy
$366,920
$410,296

Other Postretirement Benefits

Entergy also currently offers retiree medical, dental, vision, and life insurance benefits (other postretirement benefits) for eligible retired employees. Employees who commenced employment before July 1, 2014 and who satisfy certain eligibility requirements (including retiring from Entergy after a certain age and/or years of service with Entergy and immediately commencing their Entergy pension benefit), may become eligible for other postretirement benefits.

In March 2020, Entergy announced changes to its other postretirement benefits. Effective January 1, 2021, certain retired, former non-bargaining employees age 65 and older who are eligible for Entergy-sponsored retiree welfare benefits, and their eligible spouses who are age 65 and older (collectively, Medicare-eligible participants), will be eligible to participate in a new Entergy-sponsored retiree health plan, and will no longer be eligible for retiree coverage under the Entergy Corporation Companies’ Benefits Plus Medical, Dental and Vision Plans. Under the new Entergy retiree health plan, Medicare-eligible participants will be eligible to participate in a health reimbursement arrangement which they may use towards the purchase of various types of qualified insurance offered through a Medicare exchange provider and for other qualified medical expenses. In accordance with accounting standards, the effects of this change are reflected in the December 31, 2020 other postretirement obligation. The changes affecting active bargaining unit employees will be negotiated with the unions prior to implementation, where necessary, and to the extent required by law.
Effective January 1, 1993, Entergy adopted an accounting standard requiring a change from a cash method to an accrual method of accounting for postretirement benefits other than pensions. Entergy Arkansas, Entergy Mississippi, Entergy New Orleans, and Entergy Texas have received regulatory approval to recover accrued other postretirement benefit costs through rates. The LPSC ordered Entergy Louisiana to continue the use of the pay-as-you-go method for ratemaking purposes for postretirement benefits other than pensions. However, the LPSC retains the flexibility to examine individual companies’ accounting for other postretirement benefits to determine if special exceptions to this order are warranted. Pursuant to regulatory directives, Entergy Arkansas, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy contribute the other postretirement benefit costs collected in rates into external trusts. System Energy is funding, on behalf of Entergy Operations, other postretirement benefits associated with Grand Gulf.

Trust assets contributed by participating Registrant Subsidiaries are in master trusts, established by Entergy Corporation and maintained by a trustee. Each participating Registrant Subsidiary holds a beneficial interest in the trusts’ assets. The assets in the master trusts are commingled for investment and administrative purposes. Although assets are commingled, supporting records are maintained for the purpose of allocating the beneficial interest in net earnings/(losses) and the administrative expenses of the investment accounts to the various participating plans and participating Registrant Subsidiaries. Beneficial interest in an investment account’s net income/(loss) is comprised of interest and dividends, realized and unrealized gains and losses, and expenses. Beneficial interest from these investments is allocated to the plans and participating Registrant Subsidiary based on their portion of net assets in the pooled accounts.

Components of Net Other Postretirement Benefit Cost and Other Amounts Recognized as a Regulatory Asset and/or AOCI

Total 2021, 2020, and 2019 other postretirement benefit costs of the Registrant Subsidiaries, including amounts capitalized and deferred, for their employees included the following components:
2021
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
Other postretirement costs:
Service cost - benefits earned during the period
$4,135
$6,174
$1,448
$437
$1,384
$1,340
Interest cost on APBO
3,726
4,520
1,110
521
1,269
878
Expected return on assets
(18,020)
(5,536)
(5,750)
(10,192)
(3,156)
Amortization of prior service credit
(1,121)
(4,920)
(1,775)
(916)
(3,742)
(436)
Recognized net (gain)/ loss
196
(364)
76
(712)
398
61
Net other postretirement benefit (income)/cost
($11,084)
$5,410
($4,677)
($6,420)
($10,883)
($1,313)
Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax)
Arising this period:
Prior service cost/(credit) for the period
($85)
$357
$—
$—
($3,776)
$69
Net (gain)/loss
$9,956
($2,367)
($2,823)
($3,330)
$939
$210
Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year:
Amortization of prior service credit
1,121
4,920
1,775
916
3,742
436
Amortization of net (gain)/loss
(196)
364
(76)
712
(398)
(61)
Total
$10,796
$3,274
($1,124)
($1,702)
$507
$654
Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax)
($288)
$8,684
($5,801)
($8,122)
($10,376)
($659)

2020
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
(In Thousands)
Other postretirement costs:
Service cost - benefits earned during the period
$3,626
$5,993
$1,468
$445
$1,219
$1,254
Interest cost on APBO
4,712
6,216
1,536
784
2,008
1,130
Expected return on assets
(17,104)
(5,167)
(5,382)
(9,643)
(2,958)
Amortization of prior service credit
(1,849)
(6,179)
(1,652)
(763)
(3,364)
(1,065)
Recognized net (gain)/loss
540
(447)
171
(13)
907
121
Net other postretirement benefit (income)/cost
($10,075)
$5,583
($3,644)
($4,929)
($8,873)
($1,518)
Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax)
Arising this period:
Prior service cost/(credit) for the period
$12,320
($23,508)
($4,428)
($5,493)
($22,441)
($1,963)
Net (gain)/loss
$2,245
$8,744
($4,456)
($5,351)
($3,266)
$58
Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year:
Amortization of prior service credit
1,849
6,179
1,652
763
3,364
1,065
Amortization of net (gain)/ loss
(540)
447
(171)
13
(907)
(121)
Total
$15,874
($8,138)
($7,403)
($10,068)
($23,250)
($961)
Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax)
$5,799
($2,555)
($11,047)
($14,997)
($32,123)
($2,479)

2019
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
(In Thousands)
Other postretirement costs:
Service cost - benefits earned during the period
$2,363
$4,639
$1,046
$367
$943
$973
Interest cost on APBO
7,226
10,664
2,681
1,581
3,415
1,902
Expected return on assets
(15,962)
(4,794)
(4,947)
(9,103)
(2,788)
Amortization of prior service credit
(4,950)
(7,349)
(1,756)
(682)
(2,243)
(1,450)
Recognized net (gain)/loss
576
(695)
723
231
485
354
Net other postretirement benefit (income)/cost
($10,747)
$7,259
($2,100)
($3,450)
($6,503)
($1,009)
Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax)
Arising this period:
Net gain
(26,707)
(2,220)
(11,950)
(10,967)
(6,406)
(5,539)
Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year:
Amortization of prior service credit
4,950
7,349
1,756
682
2,243
1,450
Amortization of net (gain)/loss
(576)
695
(723)
(231)
(485)
(354)
Total
($22,333)
$5,824
($10,917)
($10,516)
($4,648)
($4,443)
Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax)
($33,080)
$13,083
($13,017)
($13,966)
($11,151)
($5,452)

Other Postretirement Benefit Obligations, Plan Assets, Funded Status, and Amounts Not Yet Recognized and Recognized in the Balance Sheet
Other postretirement benefit obligations, plan assets, funded status, and amounts not yet recognized and recognized in the Balance Sheets of the Registrant Subsidiaries as of December 31, 2021 and 2020 are as follows:

2021
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
(In Thousands)
Change in APBO
Balance at January 1
$209,369
$255,571
$61,990
$31,707
$74,233
$47,701
Service cost
4,135
6,174
1,448
437
1,384
1,340
Interest cost
3,726
4,520
1,110
521
1,269
878
Plan amendments
(85)
357
(3,776)
69
Plan participant contributions
5,637
5,186
1,386
403
1,491
1,353
Actuarial (gain)/loss
14,323
(2,367)
(1,335)
988
4,270
1,289
Benefits paid
(15,954)
(16,460)
(3,604)
(2,194)
(6,923)
(4,769)
Medicare Part D subsidy received
32
50
6
4
13
14
Balance at December 31
$221,183
$253,031
$61,001
$31,866
$71,961
$47,875
Change in Plan Assets
Fair value of assets at January 1
$304,192
$—
$93,475
$102,734
$174,096
$52,619
Actual return on plan assets
22,387
7,024
10,068
13,523
4,235
Employer contributions
(767)
11,274
(393)
126
98
1,212
Plan participant contributions
5,637
5,186
1,386
403
1,491
1,353
Benefits paid
(15,954)
(16,460)
(3,604)
(2,194)
(6,923)
(4,769)
Fair value of assets at December 31
$315,495
$—
$97,888
$111,137
$182,285
$54,650
Funded status
$94,312
($253,031)
$36,887
$79,271
$110,324
$6,775
Amounts recognized in the balance sheet
Current liabilities
$—
($15,839)
$—
$—
$—
$—
Non-current liabilities
94,312
(237,192)
36,887
79,271
110,324
6,775
Total funded status
$94,312
($253,031)
$36,887
$79,271
$110,324
$6,775
Amounts recognized in regulatory asset
Prior service cost/(credit)
$8,691
$—
($4,109)
($3,814)
($20,532)
($1,249)
Net (gain)/loss
(6,797)
(4,254)
(16,003)
2,571
2,967
$1,894
$—
($8,363)
($19,817)
($17,961)
$1,718
Amounts recognized in AOCI (before tax)
Prior service credit
$—
($16,967)
$—
$—
$—
$—
Net gain
(17,551)
$—
($34,518)
$—
$—
$—
$—
2020
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
(In Thousands)
Change in APBO
Balance at January 1
$185,744
$274,175
$65,979
$38,460
$94,742
$47,348
Service cost
3,626
5,993
1,468
445
1,219
1,254
Interest cost
4,712
6,216
1,536
784
2,008
1,130
Plan amendments
12,320
(23,508)
(4,428)
(5,493)
(22,441)
(1,963)
Plan participant contributions
7,792
8,269
2,122
1,123
2,456
1,732
Actuarial (gain)/loss
18,257
8,744
684
(91)
5,952
3,025
Benefits paid
(23,141)
(24,395)
(5,382)
(3,530)
(9,721)
(4,851)
Medicare Part D subsidy received
59
77
11
9
18
26
Balance at December 31
$209,369
$255,571
$61,990
$31,707
$74,233
$47,701
Change in Plan Assets
Fair value of assets at January 1
$284,224
$—
$86,085
$93,858
$161,810
$48,471
Actual return on plan assets
33,116
10,307
10,642
18,861
5,925
Employer contributions
2,201
16,126
343
641
690
1,342
Plan participant contributions
7,792
8,269
2,122
1,123
2,456
1,732
Benefits paid
(23,141)
(24,395)
(5,382)
(3,530)
(9,721)
(4,851)
Fair value of assets at December 31
$304,192
$—
$93,475
$102,734
$174,096
$52,619
Funded status
$94,823
($255,571)
$31,485
$71,027
$99,863
$4,918
Amounts recognized in the balance sheet
Current liabilities
$—
($15,580)
$—
$—
$—
$—
Non-current liabilities
94,823
(239,991)
31,485
71,027
99,863
4,918
Total funded status
$94,823
($255,571)
$31,485
$71,027
$99,863
$4,918
Amounts recognized in regulatory asset
Prior service cost/(credit)
$7,655
$—
($5,884)
($4,730)
($20,498)
($1,754)
Net (gain)/loss
(16,557)
(1,355)
(13,385)
2,030
2,818
($8,902)
$—
($7,239)
($18,115)
($18,468)
$1,064
Amounts recognized in AOCI (before tax)
Prior service credit
$—
($22,244)
$—
$—
$—
$—
Net gain
(15,548)
$—
($37,792)
$—
$—
$—
$—

The other postretirement plans incurred actuarial losses during 2021 primarily due to a reduction in the projected Employer Group Waiver Plan (EGWP) revenue and updated census data. These losses were partially offset by gains resulting from the actual return on assets exceeding the expected return on assets for 2021 and a rise in bond
yields that resulted in increases to the discount rates used to develop the benefit obligations. The other postretirement plans incurred actuarial losses during 2020 primarily due to a reduction in the projected EGWP revenue and a fall in bond yields that resulted in decreases to the discount rates used to develop the benefit obligations. These losses were partially offset by gains resulting from the actual return on assets exceeding the expected return on assets for 2020, an update to the latest mortality projection scale MP-2020, and favorable claims experience.

Non-Qualified Pension Plans

Entergy also sponsors non-qualified, non-contributory defined benefit pension plans that provide benefits to certain key employees.

The following Registrant Subsidiaries participate in Entergy’s non-qualified, non-contributory defined benefit pension plans that provide benefits to certain key employees. The net periodic pension cost for their employees for the non-qualified plans for 2021, 2020, and 2019, was as follows:
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
(In Thousands)
2021
$343
$307
$365
$30
$615
2020
$333
$148
$359
$31
$469
2019
$275
$159
$326
$20
$481

Included in the 2021 net periodic pension cost above are settlement charges of $155 thousand and $172 thousand for Entergy Louisiana and Entergy Texas, respectively, related to the lump sum benefits paid out of the plan. Included in the 2019 net periodic pension cost above are settlement charges of $40 thousand for Entergy Mississippi related to the lump sum benefits paid out of the plan. In 2020 there were no settlement charges related to the payment of lump sum benefits out of the plan.

The projected benefit obligation for their employees for the non-qualified plans as of December 31, 2021 and 2020 was as follows:
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
(In Thousands)
2021
$2,875
$1,469
$3,708
$1,069
$7,462
2020
$3,197
$1,965
$3,852
$247
$8,475

The accumulated benefit obligation for their employees for the non-qualified plans as of December 31, 2021 and 2020 was as follows:
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
(In Thousands)
2021
$2,482
$1,445
$3,377
$738
$7,355
2020
$2,626
$1,802
$3,345
$240
$7,949
The following amounts were recorded on the balance sheet as of December 31, 2021 and 2020:
2021
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
(In Thousands)
Current liabilities
($248)
($186)
($190)
($31)
($3,080)
Non-current liabilities
(2,627)
(1,283)
(3,518)
(1,039)
(4,382)
Total funded status
($2,875)
($1,469)
($3,708)
($1,070)
($7,462)
Regulatory asset/(liability)
$1,059
$233
$1,368
$251
($706)
Accumulated other comprehensive income (before taxes)
$—
$10
$—
$—
$—

2020
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
(In Thousands)
Current liabilities
($218)
($193)
($181)
($17)
($633)
Non-current liabilities
(2,979)
(1,772)
(3,671)
(230)
(7,842)
Total funded status
($3,197)
($1,965)
($3,852)
($247)
($8,475)
Regulatory asset/(liability)
$1,535
$424
$1,757
($558)
$147
Accumulated other comprehensive income (before taxes)
$—
$18
$—
$—
$—

The non-qualified pension plans incurred actuarial losses during 2021 primarily due to differences in recent retirement and lump sum experience relative to actuarial assumptions. The non-qualified pension plans incurred actuarial losses during 2020 primarily due to a fall in bond yields that resulted in decreases to the discount rates used to develop the benefit obligations.

Accounting for Pension and Other Postretirement Benefits

Accounting standards require an employer to recognize in its balance sheet the funded status of its benefit plans. This is measured as the difference between plan assets at fair value and the benefit obligation. Entergy uses a December 31 measurement date for its pension and other postretirement plans. Employers are to record previously unrecognized gains and losses, prior service costs, and any remaining transition asset or obligation (that resulted from adopting prior pension and other postretirement benefits accounting standards) as comprehensive income and/or as a regulatory asset reflective of the recovery mechanism for pension and other postretirement benefit costs in the Registrant Subsidiaries’ respective regulatory jurisdictions. For the portion of Entergy Louisiana that is not regulated, the unrecognized prior service cost, gains and losses, and transition asset/obligation for its pension and other postretirement benefit obligations are recorded as other comprehensive income. Entergy Louisiana recovers other postretirement benefit costs on a pay-as-you-go basis and records the unrecognized prior service cost, gains and losses, and transition obligation for its other postretirement benefit obligation as other comprehensive income. Accounting standards also require that changes in the funded status be recorded as other comprehensive income and/or a regulatory asset in the period in which the changes occur.

With regard to pension and other postretirement costs, Entergy calculates the expected return on pension and other postretirement benefit plan assets by multiplying the long-term expected rate of return on assets by the market-related value (MRV) of plan assets. In general, Entergy determines the MRV of its pension plan assets by calculating a value that uses a 20-quarter phase-in of the difference between actual and expected returns and for its other postretirement benefit plan assets Entergy generally uses fair value.
In accordance with ASU No. 2017-07, “Compensation - Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost”, the other components of net benefit cost are required to be presented in the income statement separately from the service cost component and outside a subtotal of income from operations and are presented by Entergy in miscellaneous - net in other income.

Qualified Pension Settlement Cost

Year-to-date lump sum benefit payments from the Entergy Corporation Retirement Plan for Bargaining Employees and the Entergy Corporation Retirement Plan for Non-Bargaining Employees exceeded the sum of the Plans’ 2021 service and interest cost, resulting in settlement costs. In accordance with accounting standards, settlement accounting requires immediate recognition of the portion of previously unrecognized losses associated with the settled portion of the plans’ pension liability. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy participate in one or both of the Entergy Corporation Retirement Plan for Bargaining Employees and the Entergy Corporation Retirement Plan for Non-Bargaining employees and incurred settlement costs. Similar to other pension costs, the settlement costs were included with employee labor costs and charged to expense and capital in the same manner that labor costs were charged. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans received regulatory approval to defer the expense portion of the settlement costs, with future amortization of the deferred settlement expense over the period in which the expense otherwise would be recorded had the immediate recognition not occurred.


Qualified Pension and Other Postretirement Plans’ Assets

The Plan Administrator’s trust asset investment strategy is to invest the assets in a manner whereby long-term earnings on the assets (plus cash contributions) provide adequate funding for retiree benefit payments. The mix of assets is based on an optimization study that identifies asset allocation targets in order to achieve the maximum return for an acceptable level of risk, while minimizing the expected contributions and pension and postretirement expense.

In the optimization studies, the Plan Administrator formulates assumptions about characteristics, such as expected asset class investment returns, volatility (risk), and correlation coefficients among the various asset classes. The future market assumptions used in the optimization study are determined by examining historical market characteristics of the various asset classes and making adjustments to reflect future conditions expected to prevail over the study period.

The target asset allocation for pension adjusts dynamically based on the pension plans’ funded status. The current targets are shown below. The expectation is that the allocation to fixed income securities will increase as the pension plans’ funded status increases. The following ranges were established to produce an acceptable, economically efficient plan to manage around the targets.

For postretirement assets the target and range asset allocations (as shown below) reflect recommendations made in the latest optimization study. The target asset allocations for postretirement assets adjust dynamically based on the funded status of each sub-account within each trust. The current weighted average targets shown below represent the aggregate of all targets for all sub-accounts within all trusts.
Entergy’s qualified pension and postretirement weighted-average asset allocations by asset category at December 31, 2021 and 2020 and the target asset allocation and ranges for 2021 are as follows:

Pension Asset Allocation
Target
Range
Actual 2021
Actual 2020
Domestic Equity Securities
39%
32%
to
46%
40%
38%
International Equity Securities
19%
15%
to
23%
20%
19%
Fixed Income Securities
42%
39%
to
45%
40%
42%
Other
0%
0%
to
10%
0%
1%

Postretirement Asset Allocation
Non-Taxable and Taxable
Target
Range
Actual 2021
Actual 2020
Domestic Equity Securities
25%
20%
to
30%
28%
29%
International Equity Securities
17%
12%
to
22%
17%
18%
Fixed Income Securities
58%
53%
to
63%
55%
53%
Other
0%
0%
to
5%
0%
0%

In determining its expected long-term rate of return on plan assets used in the calculation of benefit plan costs, Entergy reviews past performance, current and expected future asset allocations, and capital market assumptions of its investment consultant and some investment managers.

The expected long-term rate of return for the qualified pension plans’ assets is based primarily on the geometric average of the historical annual performance of a representative portfolio weighted by the target asset allocation defined in the table above, along with other indications of expected return on assets. The time period reflected is a long-dated period spanning several decades.

The expected long-term rate of return for the non-taxable postretirement trust assets is determined using the same methodology described above for pension assets, but the aggregate asset allocation specific to the non-taxable postretirement assets is used.

For the taxable postretirement trust assets, the investment allocation includes tax-exempt fixed income securities. This asset allocation, in combination with the same methodology employed to determine the expected return for other postretirement assets (as described above), and with a modification to reflect applicable taxes, is used to produce the expected long-term rate of return for taxable postretirement trust assets.

Concentrations of Credit Risk

Entergy’s investment guidelines mandate the avoidance of risk concentrations. Types of concentrations specified to be avoided include, but are not limited to, investment concentrations in a single entity, type of industry, foreign country, geographic area and individual security issuance. As of December 31, 2021, all investment managers and assets were materially in compliance with the approved investment guidelines, therefore there were no significant concentrations (defined as greater than 10 percent of plan assets) of credit risk in Entergy’s pension and other postretirement benefit plan assets.

Fair Value Measurements

Accounting standards provide the framework for measuring fair value. That framework provides a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value. The hierarchy gives
the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 measurements) and the lowest priority to unobservable inputs (Level 3 measurements).

The three levels of the fair value hierarchy are described below:

Level 1 - Level 1 inputs are unadjusted quoted prices for identical assets or liabilities in active markets that the Plan has the ability to access at the measurement date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis.

Level 2 - Level 2 inputs are inputs other than quoted prices included in Level 1 that are, either directly or indirectly, observable for the asset or liability at the measurement date. Assets are valued based on prices derived by an independent party that uses inputs such as benchmark yields, reported trades, broker/dealer quotes, and issuer spreads. Prices are reviewed and can be challenged with the independent parties and/or overridden if it is believed such would be more reflective of fair value. Level 2 inputs include the following:

- quoted prices for similar assets or liabilities in active markets;
- quoted prices for identical assets or liabilities in inactive markets;
- inputs other than quoted prices that are observable for the asset or liability; or
- inputs that are derived principally from or corroborated by observable market data by correlation or other means.

If an asset or liability has a specified (contractual) term, the Level 2 input must be observable for substantially the full term of the asset or liability.

Level 3 - Level 3 refers to securities valued based on significant unobservable inputs.

Assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement. The following tables set forth by level within the fair value hierarchy, measured at fair value on a recurring basis at December 31, 2021, and December 31, 2020, a summary of the investments held in the master trusts for Entergy’s qualified pension and other postretirement plans in which the Registrant Subsidiaries participate.

Qualified Defined Benefit Pension Plan Trusts

2021
Level 1
Level 2
Level 3
Total
(In Thousands)
Equity securities:
Corporate stocks:
Preferred
$16,231
(b)
$—
$—
$16,231
Common
1,001,169
(b)
1,001,169
Common collective trusts (c)
3,123,111
Fixed income securities:
U.S. Government securities
627,148
(a)
627,148
Corporate debt instruments
966,616
(a)
966,616
Registered investment companies (e)
92,347
(d)
3,004
(d)
1,129,070
Other
68,886
(f)
68,886
Other:
Insurance company general account (unallocated contracts)
5,961
(g)
5,961
Total investments
$1,109,747
$1,671,615
$—
$6,938,192
Cash
123,153
Other pending transactions
11,125
Less: Other postretirement assets included in total investments
(79,360)
Total fair value of qualified pension assets
$6,993,110

2020
Level 1
Level 2
Level 3
Total
(In Thousands)
Equity securities:
Corporate stocks:
Preferred
$15,756
(b)
$—
$—
$15,756
Common
1,031,213
(b)
1,031,213
Common collective trusts (c)
2,958,767
Fixed income securities:
U.S. Government securities
731,319
(a)
731,319
Corporate debt instruments
1,029,370
(a)
1,029,370
Registered investment companies (e)
81,800
(d)
3,076
(d)
1,128,107
Other
156
(f)
56,323
(f)
56,479
Other:
Insurance company general account (unallocated contracts)
6,253
(g)
6,253
Total investments
$1,128,925
$1,826,341
$—
$6,957,264
Cash
2,316
Other pending transactions
(29,121)
Less: Other postretirement assets included in total investments
(76,033)
Total fair value of qualified pension assets
$6,854,426

Other Postretirement Trusts
2021
Level 1
Level 2
Level 3
Total
(In Thousands)
Equity securities:
Common collective trust (c)
$312,594
Fixed income securities:
U.S. Government securities
62,240
(b)
89,951
(a)
152,191
Corporate debt instruments
152,562
(a)
152,562
Registered investment companies
28,450
(d)
28,450
Other
72,059
(f)
72,059
Total investments
$90,690
$314,572
$—
$717,856
Other pending transactions
(25,897)
Plus: Other postretirement assets included in the investments of the qualified pension trust
79,360
Total fair value of other postretirement assets
$771,319

2020
Level 1
Level 2
Level 3
Total
(In Thousands)
Equity securities:
Common collective trust (c)
$315,191
Fixed income securities:
U.S. Government securities
46,498
(b)
97,604
(a)
144,102
Corporate debt instruments
147,287
(a)
147,287
Registered investment companies
16,965
(d)
16,965
Other
60,219
(f)
60,219
Total investments
$63,463
$305,110
$—
$683,764
Other pending transactions
(21,931)
Plus: Other postretirement assets included in the investments of the qualified pension trust
76,033
Total fair value of other postretirement assets
$737,866

a.Certain fixed income debt securities (corporate, government, and securitized) are stated at fair value as determined by broker quotes.
b.Common stocks, certain preferred stocks, and certain fixed income debt securities (government) are stated at fair value determined by quoted market prices.
c.The common collective trusts hold investments in accordance with stated objectives. The investment strategy of the trusts is to capture the growth potential of equity markets by replicating the performance of a specified index. Net asset value per share of common collective trusts estimate fair value. Common collective trusts are not publicly quoted and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table, but are included in the total.
d.Registered investment companies are money market mutual funds with a stable net asset value of one dollar per share. Registered investment companies may hold investments in domestic and international bond markets or domestic equities and estimate fair value using net asset value per share.
e.Certain of these registered investment companies are not publicly quoted and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table, but are included in the total.
f.The other remaining assets are U.S. municipal and foreign government bonds stated at fair value as determined by broker quotes and quoted market values.
g.The unallocated insurance contract investments are recorded at contract value, which approximates fair value. The contract value represents contributions made under the contract, plus interest, less funds used to pay benefits and contract expenses, and less distributions to the master trust.
Estimated Future Benefit Payments

Based upon the same assumptions, Entergy expects that benefits to be paid and the Medicare Part D subsidies to be received over the next ten years for the Registrant Subsidiaries for their employees will be as follows:

Estimated Future Qualified Pension Benefits Payments
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
(In Thousands)
Year(s)
2022
$107,542
$120,365
$33,459
$13,992
$31,134
$26,953
2023
$104,328
$118,289
$33,055
$13,677
$30,381
$25,985
2024
$104,606
$117,416
$32,711
$13,333
$28,661
$26,155
2025
$102,411
$116,610
$31,838
$13,146
$26,807
$25,203
2026
$101,144
$114,232
$31,708
$12,875
$26,983
$24,939
2027 - 2031
$487,637
$534,665
$143,052
$58,299
$114,747
$123,220

Estimated Future Non-Qualified Pension Benefits Payments
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
(In Thousands)
Year(s)
2022
$248
$186
$190
$31
$3,080
2023
$383
$172
$422
$82
$441
2024
$324
$159
$504
$104
$420
2025
$689
$146
$486
$135
$398
2026
$143
$133
$412
$128
$428
2027 - 2031
$878
$503
$1,927
$782
$1,677

Estimated Future Other Postretirement Benefits Payments (before Medicare Part D Subsidy)
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
(In Thousands)
Year(s)
2022
$14,228
$15,845
$3,488
$2,449
$5,061
$2,828
2023
$13,652
$15,766
$3,550
$2,378
$4,998
$2,774
2024
$13,392
$15,404
$3,597
$2,288
$4,824
$2,668
2025
$13,021
$15,182
$3,657
$2,200
$4,686
$2,617
2026
$12,717
$14,868
$3,645
$2,096
$4,458
$2,511
2027 - 2031
$61,153
$70,094
$18,095
$9,058
$20,932
$12,474

Estimated Future Medicare Part D Subsidy
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
(In Thousands)
Year(s)
2022
$35
$6
$14
$—
$—
$1
2023
$3
$5
$15
$—
$—
$1
2024
$4
$7
$16
$—
$—
$1
2025
$4
$8
$17
$—
$—
$—
2026
$5
$7
$18
$1
$—
$1
2027 - 2031
$27
$51
$104
$—
$—
$4

Contributions

The Registrant Subsidiaries expect to contribute approximately the following to the qualified pension and other postretirement plans for their employees in 2022:
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
(In Thousands)
Pension Contributions
$40,840
$22,917
$12,852
$922
$1,924
$12,760
Other Postretirement Contributions
$517
$15,845
$130
$175
$66
$22

Actuarial Assumptions

The significant actuarial assumptions used in determining the pension PBO and the other postretirement benefit APBO as of December 31, 2021 and 2020 were as follows:
2021
2020
Weighted-average discount rate:
Qualified pension
2.99% - 3.08% Blended 3.05%
2.60% - 2.83% Blended 2.77%
Other postretirement
2.94%
2.62%
Non-qualified pension
2.11%
1.61%
Weighted-average rate of increase in future compensation levels
3.98% - 4.40%
3.98% - 4.40%
Interest crediting rate
2.60%
2.60%
Assumed health care trend rate:
Pre-65
5.65%
5.87%
Post-65
5.90%
6.31%
Ultimate rate
4.75%
4.75%
Year ultimate rate is reached and beyond:
Pre-65
2032
2030
Post-65
2032
2028

The significant actuarial assumptions used in determining the net periodic pension and other postretirement benefit costs for 2021, 2020, and 2019 were as follows:
2021
2020
2019
Weighted-average discount rate:
Qualified pension:
Service cost
2.81%
3.42%
4.57%
Interest cost
2.08%
2.99%
4.15%
Other postretirement:
Service cost
2.98%
3.27%
4.62%
Interest cost
1.86%
2.41%
4.01%
Non-qualified pension:
Service cost
1.48%
2.71%
3.94%
Interest cost
2.14%
2.25%
3.46%
Weighted-average rate of increase in future compensation levels
3.98% - 4.40%
3.98% - 4.40%
3.98%
Expected long-term rate of return on plan assets:
Pension assets
6.75%
7.00%
7.25%
Other postretirement non-taxable assets
6.00% - 6.75%
6.25% - 7.25%
6.50% - 7.50%
Other postretirement taxable assets
5.00%
5.25%
5.50%
Assumed health care trend rate:
Pre-65
5.87%
6.13%
6.59%
Post-65
6.31%
6.25%
7.15%
Ultimate rate
4.75%
4.75%
4.75%
Year ultimate rate is reached and beyond:
Pre-65
2030
2027
2027
Post-65
2028
2027
2026


With respect to the mortality assumptions, Entergy used the Pri-2012 Employee and Healthy Annuitant Tables with a fully generational MP-2020 projection scale, in determining its December 31, 2021 and 2020 pension plans’ PBOs and the Pri.H 2012 (headcount weighted) Employee and Healthy Annuitant Tables with a fully generational MP-2020 projection scale, in determining its December 31, 2021 and 2020 other postretirement benefit APBO.

Defined Contribution Plans

Entergy sponsors the Savings Plan of Entergy Corporation and Subsidiaries (System Savings Plan). The System Savings Plan is a defined contribution plan covering eligible employees of Entergy and certain of its subsidiaries. The participating Entergy subsidiary makes matching contributions to the System Savings Plan for all eligible participating employees in an amount equal to either 70% or 100% of the participants’ basic contributions, up to 6% of their eligible earnings per pay period. The matching contribution is allocated to investments as directed by the employee.

Entergy also sponsors the Savings Plan of Entergy Corporation and Subsidiaries VI (established in April 2007) and the Savings Plan of Entergy Corporation and Subsidiaries VII (established in April 2007) to which matching contributions are also made. The plans are defined contribution plans that cover eligible employees, as defined by each plan, of Entergy and certain of its subsidiaries.

Entergy also sponsors the Savings Plan of Entergy Corporation and Subsidiaries VIII (established January 2021) and the Savings Plan of Entergy Corporation and Subsidiaries IX (established January 2021) to which company contributions are made. The participating Entergy subsidiary makes matching contributions to these defined contribution plans for all eligible participating employees in an amount equal to 100% of the participants’
basic contributions, up to 5% of their eligible earnings per pay period. Eligible participants may also receive a discretionary annual company contribution up to 4% of the participant’s eligible earnings (subject to vesting).

The Registrant Subsidiaries’ 2021, 2020, and 2019 contributions to defined contribution plans for their employees were as follows:


Year
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
(In Thousands)
2021
$4,820
$6,678
$3,045
$1,140
$2,699
2020
$4,515
$6,518
$2,863
$1,115
$2,596
2019
$4,111
$5,641
$2,424
$882
$2,136

NOTE 12. STOCK-BASED COMPENSATION

Note 12 to the financial statements is not applicable to the Registrant Subsidiaries.

NOTE 13. BUSINESS SEGMENT INFORMATION

Registrant Subsidiaries

Each of the Registrant Subsidiaries has one reportable segment, which is an integrated utility business, except for System Energy, which is an electricity generation business. Each of the Registrant Subsidiaries’ operations is managed on an integrated basis by that company because of the substantial effect of cost-based rates and regulatory oversight on the business process, cost structures, and operating results.

NOTE 14. ACQUISITIONS

Note 14 to the financial statements is not applicable to Entergy Mississippi.

NOTE 15. RISK MANAGEMENT AND FAIR VALUES

Market Risk

In the normal course of business, Entergy is exposed to a number of market risks. Market risk is the potential loss that Entergy may incur as a result of changes in the market or fair value of a particular commodity or instrument. All financial and commodity-related instruments, including derivatives, are subject to market risk including commodity price risk, equity price, and interest rate risk. Entergy uses derivatives primarily to mitigate commodity price risk, particularly power price and fuel price risk.

The Utility has limited exposure to the effects of market risk because it operates primarily under cost-based rate regulation. To the extent approved by their retail regulators, the Utility operating companies use derivative instruments to hedge the exposure to price volatility inherent in their purchased power, fuel, and gas purchased for resale costs, that are recovered from customers.

Entergy’s exposure to market risk is determined by a number of factors, including the size, term, composition, and diversification of positions held, as well as market volatility and liquidity. For instruments such as options, the time period during which the option may be exercised and the relationship between the current
market price of the underlying instrument and the option’s contractual strike or exercise price also affects the level of market risk. A significant factor influencing the overall level of market risk to which Entergy is exposed is its use of hedging techniques to mitigate such risk. Hedging instruments and volumes are chosen based on ability to mitigate risk associated with future energy and capacity prices; however, other considerations are factored into hedge product and volume decisions including corporate liquidity, corporate credit ratings, counterparty credit risk, hedging costs, firm settlement risk, and product availability in the marketplace. Entergy manages market risk by actively monitoring compliance with stated risk management policies as well as monitoring the effectiveness of its hedging policies and strategies. Entergy’s risk management policies limit the amount of total net exposure and rolling net exposure during the stated periods. These policies, including related risk limits, are regularly assessed to ensure their appropriateness given Entergy’s objectives.

Derivatives

Some derivative instruments are classified as cash flow hedges due to their financial settlement provisions while others are classified as normal purchase/normal sale transactions due to their physical settlement provisions. Normal purchase/normal sale risk management tools include power purchase and sales agreements, fuel purchase agreements, capacity contracts, and tolling agreements. Financially-settled cash flow hedges can include natural gas and electricity swaps and options. Entergy may enter into financially-settled swap and option contracts to manage market risk that may or may not be designated as hedging instruments.

Entergy used standardized master netting agreements to help mitigate the credit risk of derivative instruments. These master agreements facilitated the netting of cash flows associated with a single counterparty and may have included collateral requirements. Cash, letters of credit, and parental/affiliate guarantees were obtained as security from counterparties in order to mitigate credit risk. The collateral agreements required a counterparty to post cash or letters of credit in the event an exposure exceeded an established threshold. The threshold represented an unsecured credit limit, which may have been supported by a parental/affiliate guarantee, as determined in accordance with Entergy’s credit policy. In addition, collateral agreements allowed for termination and liquidation of all positions in the event of a failure or inability to post collateral.

Entergy manages fuel price volatility for its Louisiana jurisdictions (Entergy Louisiana and Entergy New Orleans) and Entergy Mississippi through the purchase of natural gas swaps and options that financially settle against either the average Henry Hub Gas Daily prices or the NYMEX Henry Hub. These swaps and options are marked-to-market through fuel expense with offsetting regulatory assets or liabilities. All benefits or costs of the program are recorded in fuel costs. The notional volumes of these swaps are based on a portion of projected annual exposure to gas price volatility for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy New Orleans. The maximum length of time over which Entergy has executed natural gas swaps and options as of December 31, 2021 is 2.25 years for Entergy Louisiana and the maximum length of time over which Entergy has executed natural gas swaps as of December 31, 2021 is 10 months for Entergy Mississippi and 3 months for Entergy New Orleans. The total volume of natural gas swaps and options outstanding as of December 31, 2021 is 33,083,500 MMBtu for Entergy, including 16,420,000 MMBtu for Entergy Louisiana, 16,017,800 MMBtu for Entergy Mississippi, and 645,700 MMBtu for Entergy New Orleans. Credit support for these natural gas swaps and options is covered by master agreements that do not require Entergy to provide collateral based on mark-to-market value, but do carry adequate assurance language that may lead to requests for collateral.

During the second quarter 2021, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2021 through May 31, 2022. Financial transmission rights are derivative instruments that represent economic hedges of future congestion charges that will be incurred in serving Entergy’s customer load. They are not designated as hedging instruments. Entergy initially records
financial transmission rights at their estimated fair value and subsequently adjusts the carrying value to their estimated fair value at the end of each accounting period prior to settlement. Unrealized gains or losses on financial transmission rights held by Entergy Wholesale Commodities are included in operating revenues. The Utility operating companies recognize regulatory liabilities or assets for unrealized gains or losses on financial transmission rights. The total volume of financial transmission rights outstanding as of December 31, 2021 is 57,836 GWh for Entergy, including 12,561 GWh for Entergy Arkansas, 25,973 GWh for Entergy Louisiana, 6,429 GWh for Entergy Mississippi, 2,643 GWh for Entergy New Orleans, and 10,003 GWh for Entergy Texas. Credit support for financial transmission rights held by the Utility operating companies is covered by cash and/or letters of credit issued by each Utility operating company as required by MISO. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Mississippi and Entergy Texas as of December 31, 2021 and for Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas as of December 31, 2020.

The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2021 and 2020 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging.
Instrument
Balance Sheet Location
Gross Fair Value (a)
Offsetting Position (b)
Net Fair Value (c) (d)
Registrant
(In Millions)
2021
Assets:
Natural gas swaps and options
Prepayments and other
$5.7
$—
$5.7
Entergy Louisiana
Natural gas swaps and options
Other deferred debits and other assets
$5.3
$—
$5.3
Entergy Louisiana
Financial transmission rights
Prepayments and other
$2.3
$—
$2.3
Entergy Arkansas
Financial transmission rights
Prepayments and other
$0.6
$—
$0.6
Entergy Louisiana
Financial transmission rights
Prepayments and other
$0.3
$—
$0.3
Entergy Mississippi
Financial transmission rights
Prepayments and other
$0.1
$—
$0.1
Entergy New Orleans
Financial transmission rights
Prepayments and other
$0.8
$—
$0.8
Entergy Texas
Liabilities:
Natural gas swaps
Other current liabilities
$6.7
$—
$6.7
Entergy Mississippi
Natural gas swaps
Other current liabilities
$0.5
$—
$0.5
Entergy New Orleans

Instrument
Balance Sheet Location
Gross Fair Value (a)
Offsetting Position (b)
Net Fair Value (c) (d)
Registrant
2020
Assets:
Natural gas swaps and options
Prepayments and other
$0.8
$—
$0.8
Entergy Louisiana
Natural gas swaps and options
Other deferred debits and other assets
$0.5
$—
$0.5
Entergy Louisiana
Financial transmission rights
Prepayments and other
$2.9
($0.2)
$2.7
Entergy Arkansas
Financial transmission rights
Prepayments and other
$4.3
($0.1)
$4.2
Entergy Louisiana
Financial transmission rights
Prepayments and other
$0.6
$—
$0.6
Entergy Mississippi
Financial transmission rights
Prepayments and other
$0.2
($0.1)
$0.1
Entergy New Orleans
Financial transmission rights
Prepayments and other
$1.6
$—
$1.6
Entergy Texas
Liabilities:
Natural gas swaps and options
Other current liabilities
$0.3
$—
$0.3
Entergy Louisiana
Natural gas swaps and options
Other non-current liabilities
$1.3
$—
$1.3
Entergy Louisiana
Natural gas swaps
Other current liabilities
$5.0
$—
$5.0
Entergy Mississippi
Natural gas swaps
Other current liabilities
$0.3
$—
$0.3
Entergy New Orleans

a.Represents the gross amounts of recognized assets/liabilities
b.Represents the netting of fair value balances with the same counterparty
c.Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets
d.As of December 31, 2021 letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi and $0.1 million for Entergy Texas. As of December 31, 2020, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Louisiana, $0.2 million for Entergy Mississippi, $0.2 million for Entergy New Orleans, and $0.5 million for Entergy Texas.

The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the years ended December 31, 2021, 2020, and 2019 are as follows:

Instrument
Income Statement Location
Amount of gain (loss) recorded in the income statement
Registrant
(In Millions)
2021
Natural gas swaps and options
Fuel, fuel-related expenses, and gas purchased for resale
$12.6
(a)
Entergy Louisiana
Natural gas swaps
Fuel, fuel-related expenses, and gas purchased for resale
$19.8
(a)
Entergy Mississippi
Natural gas swaps
Fuel, fuel-related expenses, and gas purchased for resale
($0.1)
(a)
Entergy New Orleans
Financial transmission rights
Purchased power
$42.6
(b)
Entergy Arkansas
Financial transmission rights
Purchased power
$31.6
(b)
Entergy Louisiana
Financial transmission rights
Purchased power
$11.3
(b)
Entergy Mississippi
Financial transmission rights
Purchased power
$4.3
(b)
Entergy New Orleans
Financial transmission rights
Purchased power
$85.9
(b)
Entergy Texas
2020
Natural gas swaps
Fuel, fuel-related expenses, and gas purchased for resale
($11.1)
(a)
Entergy Mississippi
Natural gas swaps
Fuel, fuel-related expenses, and gas purchased for resale
($0.8)
(a)
Entergy New Orleans
Financial transmission rights
Purchased power
$26.7
(b)
Entergy Arkansas
Financial transmission rights
Purchased power
$19.6
(b)
Entergy Louisiana
Financial transmission rights
Purchased power
$3.0
(b)
Entergy Mississippi
Financial transmission rights
Purchased power
$1.4
(b)
Entergy New Orleans
Financial transmission rights
Purchased power
$40.4
(b)
Entergy Texas
2019
Natural gas swaps and options
Fuel, fuel-related expenses, and gas purchased for resale
($5.3)
(a)
Entergy Louisiana
Natural gas swaps
Fuel, fuel-related expenses, and gas purchased for resale
($7.7)
(a)
Entergy Mississippi
Financial transmission rights
Purchased power
$22.3
(b)
Entergy Arkansas
Financial transmission rights
Purchased power
$46.7
(b)
Entergy Louisiana
Financial transmission rights
Purchased power
$6.8
(b)
Entergy Mississippi
Financial transmission rights
Purchased power
$2.7
(b)
Entergy New Orleans
Financial transmission rights
Purchased power
$15.7
(b)
Entergy Texas
a.Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms.
b.Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses
recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms.

Fair Values

The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling. Considerable judgment is required in developing the estimates of fair value. Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange. Gains or losses realized on financial instruments are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments.

Accounting standards define fair value as an exit price, or the price that would be received to sell an asset or the amount that would be paid to transfer a liability in an orderly transaction between knowledgeable market participants at the date of measurement. Entergy and the Registrant Subsidiaries use assumptions or market input data that market participants would use in pricing assets or liabilities at fair value. The inputs can be readily observable, corroborated by market data, or generally unobservable. Entergy and the Registrant Subsidiaries endeavor to use the best available information to determine fair value.

Accounting standards establish a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy establishes the highest priority for unadjusted market quotes in an active market for the identical asset or liability and the lowest priority for unobservable inputs.

The three levels of the fair value hierarchy are:

Level 1 - Level 1 inputs are unadjusted quoted prices in active markets for identical assets or liabilities that the entity has the ability to access at the measurement date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis. Level 1 primarily consists of individually owned common stocks, cash equivalents (temporary cash investments, securitization recovery trust account, and escrow accounts), debt instruments, and gas swaps traded on exchanges with active markets. Cash equivalents includes all unrestricted highly liquid debt instruments with an original or remaining maturity of three months or less at the date of purchase.

Level 2 - Level 2 inputs are inputs other than quoted prices included in Level 1 that are, either directly or indirectly, observable for the asset or liability at the measurement date. Assets are valued based on prices derived by independent third parties that use inputs such as benchmark yields, reported trades, broker/dealer quotes, and issuer spreads. Prices are reviewed and can be challenged with the independent parties and/or overridden by Entergy if it is believed such would be more reflective of fair value. Level 2 inputs include the following:

quoted prices for similar assets or liabilities in active markets;
quoted prices for identical assets or liabilities in inactive markets;
inputs other than quoted prices that are observable for the asset or liability; or
inputs that are derived principally from or corroborated by observable market data by correlation or other means.
Level 2 consists primarily of individually-owned debt instruments and gas swaps and options valued using observable inputs.

Level 3 - Level 3 inputs are pricing inputs that are generally less observable or unobservable from objective sources. These inputs are used with internally developed methodologies to produce management’s best estimate of fair value for the asset or liability. Level 3 consists primarily of financial transmission rights and derivative power contracts used as cash flow hedges of power sales at merchant power plants.

The amounts reflected as the fair value of electricity swaps were based on the estimated amount that the contracts were in-the-money at the balance sheet date (treated as an asset) or out-of-the-money at the balance sheet date (treated as a liability) and equaled the estimated amount receivable to or payable by Entergy if the contracts were settled at that date. These derivative contracts included cash flow hedges that swapped fixed for floating cash flows for sales of the output from the Entergy Wholesale Commodities business. The fair values were based on the mark-to-market comparison between the fixed contract prices and the floating prices determined each period from quoted forward power market prices. The differences between the fixed price in the swap contract and these market-related prices multiplied by the volume specified in the contract and discounted at the counterparties’ credit adjusted risk free rate were recorded as derivative contract assets or liabilities. For contracts that had unit contingent terms, a further discount was applied based on the historical relationship between contract and market prices for similar contract terms.

The amounts reflected as the fair values of electricity options were valued based on a Black Scholes model, and were calculated at the end of each month for accounting purposes. Inputs to the valuation included end of day forward market prices for the period when the transactions settled, implied volatilities based on market volatilities provided by a third-party data aggregator, and U.S. Treasury rates for a risk-free return rate. As described further below, prices and implied volatilities were reviewed and could be adjusted if it was determined that there was a better representation of fair value.

On a daily basis, the Office of Corporate Risk Oversight calculated the mark-to-market for electricity swaps and options. The Office of Corporate Risk Oversight also validated forward market prices by comparing them to other sources of forward market prices or to settlement prices of actual market transactions. Significant differences were analyzed and potentially adjusted based on these other sources of forward market prices or settlement prices of actual market transactions. Implied volatilities used to value options were also validated using actual counterparty quotes for Entergy Wholesale Commodities transactions when available and compared with other sources of market implied volatilities. Moreover, on a quarterly basis, the Office of Corporate Risk Oversight confirmed the mark-to-market calculations and prepared price scenarios and credit downgrade scenario analysis. The scenario analysis was communicated to senior management within Entergy and within Entergy Wholesale Commodities. Finally, for all proposed derivative transactions, an analysis was completed to assess the risk of adding the proposed derivative to Entergy Wholesale Commodities’ portfolio. In particular, the credit and liquidity effects were calculated for this analysis. This analysis was communicated to senior management within Entergy and Entergy Wholesale Commodities.

The values of financial transmission rights are based on unobservable inputs, including estimates of congestion costs in MISO between applicable generation and load pricing nodes based on the 50th percentile of historical prices. They are classified as Level 3 assets and liabilities. The valuations of these assets and liabilities are performed by the Office of Corporate Risk Oversight. The values are calculated internally and verified against the data published by MISO. Entergy’s Entergy Wholesale Commodities Accounting group reviews these valuations for reasonableness, with the assistance of others within the organization with knowledge of the various inputs and assumptions used in the valuation. The Office of Corporate Risk Oversight reports to the Vice
President and Treasurer. The Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer.

The following table sets forth, by level within the fair value hierarchy, the Registrant Subsidiaries’ assets and liabilities that are accounted for at fair value on a recurring basis as of December 31, 2021 and December 31, 2020. The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect its placement within the fair value hierarchy levels.

Entergy Mississippi
2021
Level 1
Level 2
Level 3
Total
(In Millions)
Assets:
Temporary cash investments
$47.6
$—
$—
$47.6
Escrow accounts
48.9
48.9
Financial transmission rights
0.3
0.3
$96.5
$—
$0.3
$96.8
Liabilities:
Gas hedge contracts
$6.7
$—
$—
$6.7
2020
Level 1
Level 2
Level 3
Total
(In Millions)
Assets:
Escrow accounts
$64.6
$—
$—
$64.6
Financial transmission rights
0.6
0.6
$64.6
$—
$0.6
$65.2
Liabilities:
Gas hedge contracts
$5.0
$—
$—
$5.0

The following table sets forth a reconciliation of changes in the net assets for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the year ended December 31, 2021.
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
(In Millions)
Balance as of January 1, 2021
$2.7
$4.2
$0.6
$0.1
$1.6
Issuances of financial transmission rights
2.8
4.1
1.7
0.4
2.7
Gains (losses) included as a regulatory liability/asset
39.4
23.9
9.3
3.9
82.4
Settlements
(42.6)
(31.6)
(11.3)
(4.3)
(85.9)
Balance as of December 31, 2021
$2.3
$0.6
$0.3
$0.1
$0.8

The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the year ended December 31, 2020.
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
(In Millions)
Balance as of January 1, 2020
$3.3
$4.5
$0.8
$0.3
$0.9
Issuances of financial transmission rights
6.5
13.2
1.4
(0.1)
2.4
Gains (losses) included as a regulatory liability/asset
19.6
6.1
1.4
1.3
38.7
Settlements
(26.7)
(19.6)
(3.0)
(1.4)
(40.4)
Balance as of December 31, 2020
$2.7
$4.2
$0.6
$0.1
$1.6

NOTE 16. DECOMMISSIONING TRUST FUNDS

Note 16 to the financial statements is not applicable for Entergy Mississippi.

NOTE 17. VARIABLE INTEREST ENTITIES

Note 17 to the financial statements is not applicable to the presentation of the FERC Form 1.

NOTE 18. TRANSACTIONS WITH AFFILIATES

Each Registrant Subsidiary purchases electricity from or sells electricity to the other Registrant Subsidiaries, or both, under rate schedules filed with the FERC. The Registrant Subsidiaries receive management, technical, advisory, operating, and administrative services from Entergy Services; and receive management, technical, and operating services from Entergy Operations. These transactions are on an “at cost” basis.

As described in Note 4 to the financial statements, the Registrant Subsidiaries participate in Entergy’s money pool and earn interest income from the money pool.

The tables below contain the various affiliate transactions of the Utility operating companies, System Energy, and other Entergy affiliates.

Intercompany Revenues

Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
(In Millions)
2021
$109.8
$289.9
$1.4
$—
$64.3
$545.6
2020
$105.2
$280.5
$1.2
$—
$40.4
$520.7
2019
$117.5
$277.8
$1.4
$—
$51.6
$584.1

Intercompany Operating Expenses
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
(In Millions)
2021
$559.7
$755.2
$299.8
$287.8
$275.0
$190.8
2020
$515.5
$661.5
$283.3
$266.0
$260.3
$177.4
2019
$534.0
$665.4
$306.7
$292.1
$255.0
$156.2

Intercompany Interest and Investment Income

Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
(In Millions)
2021
$—
$127.6
$—
$—
$—
$—
2020
$—
$127.7
$0.1
$—
$—
$0.2
2019
$0.4
$128.5
$0.4
$—
$0.4
$1.0

NOTE 19. SUBSEQUENT EVENT

Management has evaluated the impact of events occurring after December 31, 2021 up to April 15, 2022, the date that Entergy Mississippi's FERC financial statements and disclosures were filed. These financial statements include all necessary adjustments and disclosures resulting from these evaluations.


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
STATEMENTS OF ACCUMULATED COMPREHENSIVE INCOME, COMPREHENSIVE INCOME, AND HEDGING ACTIVITIES
  1. Report in columns (b),(c),(d) and (e) the amounts of accumulated other comprehensive income items, on a net-of-tax basis, where appropriate.
  2. Report in columns (f) and (g) the amounts of other categories of other cash flow hedges.
  3. For each category of hedges that have been accounted for as "fair value hedges", report the accounts affected and the related amounts in a footnote.
  4. Report data on a year-to-date basis.
Line No.
Item
(a)
Unrealized Gains and Losses on Available-For-Sale Securities
(b)
Minimum Pension Liability Adjustment (net amount)
(c)
Foreign Currency Hedges
(d)
Other Adjustments
(e)
Other Cash Flow Hedges Interest Rate Swaps
(f)
Other Cash Flow Hedges [Specify]
(g)
Totals for each category of items recorded in Account 219
(h)
Net Income (Carried Forward from Page 116, Line 78)
(i)
Total Comprehensive Income
(j)
1
Balance of Account 219 at Beginning of Preceding Year
2
Preceding Quarter/Year to Date Reclassifications from Account 219 to Net Income
3
Preceding Quarter/Year to Date Changes in Fair Value
4
Total (lines 2 and 3)
140,583,075
5
Balance of Account 219 at End of Preceding Quarter/Year
6
Balance of Account 219 at Beginning of Current Year
7
Current Quarter/Year to Date Reclassifications from Account 219 to Net Income
8
Current Quarter/Year to Date Changes in Fair Value
9
Total (lines 7 and 8)
166,834,143
10
Balance of Account 219 at End of Current Quarter/Year


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
SUMMARY OF UTILITY PLANT AND ACCUMULATED PROVISIONS FOR DEPRECIATION. AMORTIZATION AND DEPLETION

Report in Column (c) the amount for electric function, in column (d) the amount for gas function, in column (e), (f), and (g) report other (specify) and in column (h) common function.

Line No.
Classification
(a)
Total Company For the Current Year/Quarter Ended
(b)
Electric
(c)
Gas
(d)
Other (Specify)
(e)
Other (Specify)
(f)
Other (Specify)
(g)
Common
(h)
1
UtilityPlantAbstract
UTILITY PLANT
2
UtilityPlantInServiceAbstract
In Service
3
UtilityPlantInServiceClassified
Plant in Service (Classified)
5,906,090,117
5,906,090,117
4
UtilityPlantInServicePropertyUnderCapitalLeases
Property Under Capital Leases
(a)
25,945,406
25,945,406
5
UtilityPlantInServicePlantPurchasedOrSold
Plant Purchased or Sold
6
UtilityPlantInServiceCompletedConstructionNotClassified
Completed Construction not Classified
600,520,068
600,520,068
7
UtilityPlantInServiceExperimentalPlantUnclassified
Experimental Plant Unclassified
8
UtilityPlantInServiceClassifiedAndUnclassified
Total (3 thru 7)
6,532,555,591
6,532,555,591
9
UtilityPlantLeasedToOthers
Leased to Others
10
UtilityPlantHeldForFutureUse
Held for Future Use
220,455
220,455
11
ConstructionWorkInProgress
Construction Work in Progress
95,935,092
95,935,092
12
UtilityPlantAcquisitionAdjustment
Acquisition Adjustments
83,828,314
83,828,314
13
UtilityPlantAndConstructionWorkInProgress
Total Utility Plant (8 thru 12)
6,712,539,452
6,712,539,452
14
AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility
Accumulated Provisions for Depreciation, Amortization, & Depletion
(b)
1,991,077,854
1,991,077,854
15
UtilityPlantNet
Net Utility Plant (13 less 14)
4,721,461,598
4,721,461,598
16
DetailOfAccumulatedProvisionsForDepreciationAmortizationAndDepletionAbstract
DETAIL OF ACCUMULATED PROVISIONS FOR DEPRECIATION, AMORTIZATION AND DEPLETION
17
AccumulatedProvisionForDepreciationAmortizationAndDepletionUtilityPlantInServiceAbstract
In Service:
18
DepreciationUtilityPlantInService
Depreciation
1,757,306,960
1,757,306,960
19
AmortizationAndDepletionOfProducingNaturalGasLandAndLandRightsutilityPlantInService
Amortization and Depletion of Producing Natural Gas Land and Land Rights
20
AmortizationOfUndergroundStorageLandAndLandRightsutilityPlantInService
Amortization of Underground Storage Land and Land Rights
21
AmortizationOfOtherUtilityPlantUtilityPlantInService
Amortization of Other Utility Plant
(c)
215,967,038
215,967,038
22
DepreciationAmortizationAndDepletionUtilityPlantInService
Total in Service (18 thru 21)
1,973,273,998
1,973,273,998
23
DepreciationAmortizationAndDepletionUtilityPlantLeasedToOthersAbstract
Leased to Others
24
DepreciationUtilityPlantLeasedToOthers
Depreciation
25
AmortizationAndDepletionUtilityPlantLeasedToOthers
Amortization and Depletion
26
DepreciationAmortizationAndDepletionUtilityPlantLeasedToOthers
Total Leased to Others (24 & 25)
27
DepreciationAndAmortizationUtilityPlantHeldForFutureUseAbstract
Held for Future Use
28
DepreciationUtilityPlantHeldForFutureUse
Depreciation
6,808
6,808
29
AmortizationUtilityPlantHeldForFutureUse
Amortization
30
DepreciationAndAmortizationUtilityPlantHeldForFutureUse
Total Held for Future Use (28 & 29)
6,808
6,808
31
AbandonmentOfLeases
Abandonment of Leases (Natural Gas)
32
AmortizationOfPlantAcquisitionAdjustment
Amortization of Plant Acquisition Adjustment
17,797,048
17,797,048
33
AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility
Total Accum Prov (equals 14) (22,26,30,31,32)
(d)
1,991,077,854
1,991,077,854


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
FOOTNOTE DATA

(a) Concept: UtilityPlantInServicePropertyUnderCapitalLeases
Includes Operating Leases recorded in accordance with FASB ASU No. 2016-02, Leases, as provided for in FERC Docket No. AI19-1-000.
(b) Concept: AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility
Includes a debit balance for removal costs of $136,760,640.
(c) Concept: AmortizationOfOtherUtilityPlantUtilityPlantInService
Includes accumulated provision for amortization of intangible assets.
(d) Concept: AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility
Includes a debit balance for removal costs of $136,760,640.

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
NUCLEAR FUEL MATERIALS (Account 120.1 through 120.6 and 157)
  1. Report below the costs incurred for nuclear fuel materials in process of fabrication, on hand, in reactor, and in cooling; owned by the respondent.
  2. If the nuclear fuel stock is obtained under leasing arrangements, attach a statement showing the amount of nuclear fuel leased, the quantity used and quantity on hand, and the costs incurred under such leasing arrangements.
Line No.
Description of item
(a)
Balance Beginning of Year
(b)
Changes during Year Additions
(c)
Changes during Year Amortization
(d)
Changes during Year Other Reductions (Explain in a footnote)
(e)
Balance End of Year
(f)
1
Nuclear Fuel in process of Refinement, Conv, Enrichment & Fab (120.1)
2
Fabrication
3
Nuclear Materials
4
Allowance for Funds Used during Construction
5
(Other Overhead Construction Costs, provide details in footnote)
6
SUBTOTAL (Total 2 thru 5)
7
Nuclear Fuel Materials and Assemblies
8
In Stock (120.2)
9
In Reactor (120.3)
10
SUBTOTAL (Total 8 & 9)
11
Spent Nuclear Fuel (120.4)
12
Nuclear Fuel Under Capital Leases (120.6)
13
(Less) Accum Prov for Amortization of Nuclear Fuel Assem (120.5)
14
TOTAL Nuclear Fuel Stock (Total 6, 10, 11, 12, less 13)
15
Estimated Net Salvage Value of Nuclear Materials in Line 9
16
Estimated Net Salvage Value of Nuclear Materials in Line 11
17
Est Net Salvage Value of Nuclear Materials in Chemical Processing
18
Nuclear Materials held for Sale (157)
19
Uranium
20
Plutonium
21
Other (Provide details in footnote)
22
TOTAL Nuclear Materials held for Sale (Total 19, 20, and 21)


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
ELECTRIC PLANT IN SERVICE (Account 101, 102, 103 and 106)
  1. Report below the original cost of electric plant in service according to the prescribed accounts.
  2. In addition to Account 101, Electric Plant in Service (Classified), this page and the next include Account 102, Electric Plant Purchased or Sold; Account 103, Experimental Electric Plant Unclassified; and Account 106, Completed Construction Not Classified-Electric.
  3. Include in column (c) or (d), as appropriate, corrections of additions and retirements for the current or preceding year.
  4. For revisions to the amount of initial asset retirement costs capitalized, included by primary plant account, increases in column (c) additions and reductions in column (e) adjustments.
  5. Enclose in parentheses credit adjustments of plant accounts to indicate the negative effect of such accounts.
  6. Classify Account 106 according to prescribed accounts, on an estimated basis if necessary, and include the entries in column (c). Also to be included in column (c) are entries for reversals of tentative distributions of the prior year reported in column (b). Likewise, if the respondent has a significant amount of plant retirements which have not been classified to primary accounts at the end of the year, include in column (d) a tentative distribution of such retirements, on an estimated basis, with appropriate contra entry to the account for accumulated depreciation provision. Include also in column (d) distributions of these tentative classifications in columns (c) and (d), including the reversals of the prior years tentative account distributions of these amounts. Careful observance of the above instructions and the texts of Accounts 101 and 106 will avoid serious omissions of the reported amount of respondent’s plant actually in service at end of year.
  7. Show in column (f) reclassifications or transfers within utility plant accounts. Include also in column (f) the additions or reductions of primary account classifications arising from distribution of amounts initially recorded in Account 102, include in column (e) the amounts with respect to accumulated provision for depreciation, acquisition adjustments, etc., and show in column (f) only the offset to the debits or credits distributed in column (f) to primary account classifications.
  8. For Account 399, state the nature and use of plant included in this account and if substantial in amount submit a supplementary statement showing subaccount classification of such plant conforming to the requirement of these pages.
  9. For each amount comprising the reported balance and changes in Account 102, state the property purchased or sold, name of vendor or purchase, and date of transaction. If proposed journal entries have been filed with the Commission as required by the Uniform System of Accounts, give also date.
Line No.
Account
(a)
Balance Beginning of Year
(b)
Additions
(c)
Retirements
(d)
Adjustments
(e)
Transfers
(f)
Balance at End of Year
(g)
1
1. INTANGIBLE PLANT
2
(301) Organization
3
(302) Franchise and Consents
4
(303) Miscellaneous Intangible Plant
326,218,182
28,787,361
58,968
354,946,575
5
TOTAL Intangible Plant (Enter Total of lines 2, 3, and 4)
326,218,182
28,787,361
58,968
354,946,575
6
2. PRODUCTION PLANT
7
A. Steam Production Plant
8
(310) Land and Land Rights
2,270,414
2,270,414
9
(311) Structures and Improvements
64,879,160
1,699,033
281,967
66,296,226
10
(312) Boiler Plant Equipment
308,407,922
6,862,747
3,007,082
312,263,587
11
(313) Engines and Engine-Driven Generators
12
(314) Turbogenerator Units
120,931,232
24,871,379
2,013,380
143,789,231
13
(315) Accessory Electric Equipment
46,062,812
1,978,661
343,681
47,697,792
14
(316) Misc. Power Plant Equipment
10,117,004
887,642
2,092
11,002,554
15
(317) Asset Retirement Costs for Steam Production
2,008,212
2,008,212
16
TOTAL Steam Production Plant (Enter Total of lines 8 thru 15)
554,676,756
36,299,462
5,648,202
585,328,016
17
B. Nuclear Production Plant
18
(320) Land and Land Rights
19
(321) Structures and Improvements
20
(322) Reactor Plant Equipment
21
(323) Turbogenerator Units
22
(324) Accessory Electric Equipment
23
(325) Misc. Power Plant Equipment
24
(326) Asset Retirement Costs for Nuclear Production
25
TOTAL Nuclear Production Plant (Enter Total of lines 18 thru 24)
26
C. Hydraulic Production Plant
27
(330) Land and Land Rights
28
(331) Structures and Improvements
29
(332) Reservoirs, Dams, and Waterways
30
(333) Water Wheels, Turbines, and Generators
31
(334) Accessory Electric Equipment
32
(335) Misc. Power Plant Equipment
33
(336) Roads, Railroads, and Bridges
34
(337) Asset Retirement Costs for Hydraulic Production
35
TOTAL Hydraulic Production Plant (Enter Total of lines 27 thru 34)
36
D. Other Production Plant
37
(340) Land and Land Rights
4,253,086
4,253,086
38
(341) Structures and Improvements
327,672,974
3,440,949
337,266
330,776,657
39
(342) Fuel Holders, Products, and Accessories
8,501,212
148,644
4,779
8,645,077
40
(343) Prime Movers
325,928,125
22,400,202
7,245,069
8,029,768
349,113,026
41
(344) Generators
237,880,612
4,720,705
1,523,895
8,029,768
233,047,654
42
(345) Accessory Electric Equipment
44,307,525
2,208,780
9,701
46,506,604
43
(346) Misc. Power Plant Equipment
6,371,538
238,626
6,610,164
44
(347) Asset Retirement Costs for Other Production
44.1
(348) Energy Storage Equipment - Production
45
TOTAL Other Prod. Plant (Enter Total of lines 37 thru 44)
954,915,072
33,157,906
9,120,710
978,952,268
46
TOTAL Prod. Plant (Enter Total of lines 16, 25, 35, and 45)
1,509,591,828
69,457,368
14,768,912
1,564,280,284
47
3. Transmission Plant
48
(350) Land and Land Rights
94,945,012
8,603,506
175
103,548,343
48.1
(351) Energy Storage Equipment - Transmission
49
(352) Structures and Improvements
62,561,654
5,204,268
132,387
862
67,632,673
50
(353) Station Equipment
672,804,435
71,864,750
4,020,034
49,766
740,599,385
51
(354) Towers and Fixtures
56,676,823
16,720
56,660,103
52
(355) Poles and Fixtures
440,645,994
72,530,133
1,386,656
511,789,471
53
(356) Overhead Conductors and Devices
313,901,263
17,697,322
1,336,365
330,262,220
54
(357) Underground Conduit
1,311
1,311
55
(358) Underground Conductors and Devices
6,310
6,310
56
(359) Roads and Trails
57
(359.1) Asset Retirement Costs for Transmission Plant
58
TOTAL Transmission Plant (Enter Total of lines 48 thru 57)
1,641,542,802
175,899,979
6,892,337
50,628
1,810,499,816
59
4. Distribution Plant
60
(360) Land and Land Rights
17,685,533
3,465,675
7,457
21,143,751
61
(361) Structures and Improvements
19,293,682
3,902,524
33,454
862
23,163,614
62
(362) Station Equipment
378,653,992
30,733,556
3,596,480
1,335,794
404,455,274
63
(363) Energy Storage Equipment – Distribution
64
(364) Poles, Towers, and Fixtures
361,934,674
59,932,393
6,267,692
21,952
415,577,423
65
(365) Overhead Conductors and Devices
466,188,994
48,684,163
8,699,709
13,649
506,159,799
66
(366) Underground Conduit
47,548,175
4,256,972
66,073
99
51,739,173
67
(367) Underground Conductors and Devices
95,126,350
9,407,734
1,236,319
915,768
104,213,533
68
(368) Line Transformers
533,023,989
83,833,543
6,959,061
14,636
609,883,835
69
(369) Services
183,057,701
6,997,850
577,770
892,127
190,369,908
70
(370) Meters
96,158,415
33,980,366
9,258,485
401,181
120,479,115
71
(371) Installations on Customer Premises
45,999,388
4,213,919
8,691,596
41,521,711
72
(372) Leased Property on Customer Premises
73
(373) Street Lighting and Signal Systems
76,215,162
12,924,762
2,814,064
86,325,860
74
(374) Asset Retirement Costs for Distribution Plant
75
TOTAL Distribution Plant (Enter Total of lines 60 thru 74)
2,320,886,055
302,333,457
48,208,160
21,644
2,575,032,996
76
5. REGIONAL TRANSMISSION AND MARKET OPERATION PLANT
77
(380) Land and Land Rights
78
(381) Structures and Improvements
79
(382) Computer Hardware
80
(383) Computer Software
81
(384) Communication Equipment
82
(385) Miscellaneous Regional Transmission and Market Operation Plant
83
(386) Asset Retirement Costs for Regional Transmission and Market Oper
84
TOTAL Transmission and Market Operation Plant (Total lines 77 thru 83)
85
6. General Plant
86
(389) Land and Land Rights
7,253,860
581,832
7,835,692
87
(390) Structures and Improvements
111,325,150
8,703,441
490,549
119,538,042
88
(391) Office Furniture and Equipment
21,641,207
2,846,349
3,960,633
445,244
20,081,679
89
(392) Transportation Equipment
261,640
261,640
90
(393) Stores Equipment
12,348
12,348
91
(394) Tools, Shop and Garage Equipment
7,327,505
1,001,002
8,328,507
92
(395) Laboratory Equipment
4,337,373
74,940
4,412,313
93
(396) Power Operated Equipment
64,407
64,407
94
(397) Communication Equipment
26,730,705
12,410,636
474,228
39,615,569
95
(398) Miscellaneous Equipment
1,593,368
106,949
1,700,317
96
SUBTOTAL (Enter Total of lines 86 thru 95)
180,470,808
25,801,904
4,451,182
28,984
201,850,514
97
(399) Other Tangible Property
98
(399.1) Asset Retirement Costs for General Plant
99
TOTAL General Plant (Enter Total of lines 96, 97, and 98)
180,470,808
25,801,904
4,451,182
28,984
201,850,514
100
TOTAL (Accounts 101 and 106)
5,978,709,675
602,280,069
74,379,559
6,506,610,185
101
(102) Electric Plant Purchased (See Instr. 8)
102
(Less) (102) Electric Plant Sold (See Instr. 8)
103
(103) Experimental Plant Unclassified
104
TOTAL Electric Plant in Service (Enter Total of lines 100 thru 103)
5,978,709,675
602,280,069
74,379,559
6,506,610,185


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
ELECTRIC PLANT LEASED TO OTHERS (Account 104)
Line No.
LesseeName
Name of Lessee
(a)
IndicationOfAssociatedCompany
* (Designation of Associated Company)
(b)
LeaseDescription
Description of Property Leased
(c)
CommissionAuthorization
Commission Authorization
(d)
ExpirationDateOfLease
Expiration Date of Lease
(e)
ElectricPlantLeasedToOthers
Balance at End of Year
(f)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47
TOTAL


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
ELECTRIC PLANT HELD FOR FUTURE USE (Account 105)
  1. Report separately each property held for future use at end of the year having an original cost of $250,000 or more. Group other items of property held for future use.
  2. For property having an original cost of $250,000 or more previously used in utility operations, now held for future use, give in column (a), in addition to other required information, the date that utility use of such property was discontinued, and the date the original cost was transferred to Account 105.
Line No.
ElectricPlantHeldForFutureUseDescription
Description and Location of Property
(a)
ElectricPlantPropertyClassifiedAsHeldForFutureUseOriginalDate
Date Originally Included in This Account
(b)
ElectricPlantPropertyClassifiedAsHeldForFutureUseExpectedUseInServiceDate
Date Expected to be used in Utility Service
(c)
ElectricPlantHeldForFutureUse
Balance at End of Year
(d)
1 Land and Rights:
2
Land and Land Rights Under $250,000
220,455
21 Other Property:
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47 TOTAL
220,455


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
CONSTRUCTION WORK IN PROGRESS - - ELECTRIC (Account 107)
  1. Report below descriptions and balances at end of year of projects in process of construction (107).
  2. Show items relating to "research, development, and demonstration" projects last, under a caption Research, Development, and Demonstrating (see Account 107 of the Uniform System of Accounts).
  3. Minor projects (5% of the Balance End of the Year for Account 107 or $1,000,000, whichever is less) may be grouped.
Line No.
ConstructionWorkInProgressProjectDescription
Description of Project
(a)
ConstructionWorkInProgress
Construction work in progress - Electric (Account 107)
(b)
1
2020 - Jackson North - Jackson Nort
181,088
2
2020 - MADISON - CANTON - 6C07 - QF
168,077
3
2020 - Madison-Yandell-GY01 & GY05-
284,520
4
2020 - RANKIN - AIRPORT - 6A04 - 55
314,271
5
2020 - SOUTHAVEN - PLUM POINT - CHU
281,754
6
2020 - VICKSBURG - VICKSBURG EAST -
448,698
7
2020 Focus 6R02 FC20M051 Rankin Rou
187,338
8
2020 Planning CL20-005V New Build N
260,306
9
2020 Planning CL20-005V Rebuild R1
114,116
10
2020 Planning CL20-005V Rep A1, RRE
378,517
11
2020 Planning RK20-010V Rebuild R2
425,921
12
2020 Planning SE17-012A Regs/RC RRE
130,581
13
2020 Planning SH20-005V Getwell - E
144,428
14
2020-Madison-Hoy Rd-Natchez Trace @
925,706
15
2020-Rankin-Henderson Rd-E Metro Pk
315,348
16
2020-SuccessAudit-SA20M011-Southave
125,642
17
2021 - Cleveland - Belzoni - 4H01 -
126,575
18
2021 - Jackson Downtown UG Network
104,942
19
2021 - Midstate - Kosciusko - Insta
987,641
20
2021 FOCUS FC21M021 Natchez 8F05 Ro
103,355
21
2021 Planning CV20-002A New Build N
120,913
22
2021 RANKIN MORTON 6R02 55Q0022
216,061
23
2021 SHN JXSNSW-KINGSW - 2 RCs
124,497
24
2021-Magee-Mendenhall-Relocate Faci
367,973
25
Add Ckt. 9A06  to Poleline for Seco
134,333
26
Clinton - Phase 1 / District 6-City
102,634
27
DeSoto County-Ross Meadows Land-M&R
108,721
28
2022-Vicksburg-Glass Road
157,421
29
Downtown Jackson - Replace 1500 KVA
145,662
30
Downtown Jackson - Replace 500 KVA
134,367
31
EMI 2021 Dec Storm
457,911
32
FC20M036 - FOCUS - 8F05 - FJ669
149,160
33
FC21M010 - FOCUS - FP02 - FP02
129,013
34
FLI-SENATOBIA NETWORK-SENATOBIA-1H0
137,443
35
FP# F1PPU27609-Brookhaven-West McCo
227,213
36
FP# F1PPU27609-FLI-Brookhaven-West
172,975
37
GM-39-3E08-C4 Capacitor Install Ree
185,884
38
GM-39-3E08-REBUILD 3PH-NURSING HOME
221,571
39
GM-39-3R02-C11 Capacitor Install Hi
182,995
40
GM-39-3R02-RC7 Capacitor removal Hi
147,969
41
GM-Guild 33-FA06-Rebuild-Cleary Rd
154,677
42
GM-Guild 33-GK01-Asset Op-Cap Bank
278,241
43
GM-Guild 33-GK01-Focus Rebuild-Fore
277,342
44
GM-Guild 33-GK01-Rebuild-Brookwood
121,881
45
GM-Vicksburg SE Guild 5F03-N6, FSW1
856,154
46
HERNANDO - 251 HWY 51 N - ASSOCIATE
123,400
47
Highway 51 Warehouse Relocation
147,261
48
Horn Lake-MS Hwy 301-Yazoo Developm
153,249
49
Horn Lake-Nail Road-Reiner Developm
111,030
50
HWY-2020-GM01-DF400-BOZEMAN RD OH 1
250,811
51
Jackson - Hwy LED Lighting
168,084
52
Madison-Hwy 43-Expedition Point Dev
129,200
53
MIDWAY RD IMPROVEMENT PROJECT - CLI
182,723
54
Natchez Trace @ Hwy 43  UG Installa
284,506
55
Nesbit-Laughter Road-Bridgforth Pro
119,028
56
Rankin -- Permanent Svc to Communit
123,104
57
Relocate Facilities W Capitol St
125,806
58
SNOWDEN PARK DIST. ROW
149,366
59
T&D - Catlett 230kv Sub - Substatio
483,560
60
T&D - Flora Add Transformer - North
342,357
61
T&D - Flora Add Transformer - West
129,286
62
T&D 2021 Rankin UG  - N1
233,221
63
Winona-623 SAWYER RD EXT WINONA,MS-
606,905
64
WINONA-SAWYER RD BIEWER LUMBER 2R04
454,453
65
WINONA-SAWYER RD-BIEWER LUMBER-EXTE
552,460
66
Other distribution lines plant
8,977,290
67
Advanced DMS
132,218
68
AMI - DMS/OMS - Software - Rel 4-5
1,166,752
69
AMI Sales and Rev BIE
238,570
70
Asset Suite/AIMM Repl - Supply Chai
5,892,167
71
CSD Workforce Management System
290,835
72
Deposit Alternative Pay
359,052
73
Digital LIHEAP
179,994
74
EML Public EV Charging Pilot
111,636
75
HER - New Desoto Service Center
8,664,582
76
MS Trans Off/Stor Facility Design
186,119
77
Power Generation Fleet Training Pla
263,024
78
SAISO Replacement
240,601
79
ServiceNow Enhancements
104,516
80
SW2 - EDE-Bill Syst Contr Repo Inte
191,797
81
Utility Data Warehouse Plus
250,957
82
Other general and intangible plant
1,002,008
83
A1A - GE LTSA Budget Cap 2020-2024
7,537,668
84
EMI Sunflower County SolarOversight
1,439,690
85
GA1 WaterWallTube & Furn Hopp Botto
219,306
86
GMS -ERDC Back-up Generator
3,440,806
87
HN1 - Hinds LTSA Capital
5,594,676
88
SPO EMISunflowerCoSolarBOTTransactn
2,247,762
89
SPO EML SunflowerTaxEquityPartneshp
822,468
90
Other production plant
96,375
91
Brookhaven Upgrade Transformer
243,078
92
Build Pine Tree 230/12.47kV Sub
515,863
93
BWSES: J2200 AT1 Spare Life Extend
228,030
94
Byram Replace Breaker FJ04
154,229
95
Byram replace FJ05 & RTU Grid Mod
225,504
96
Clinton Ind: rpl Ckt Sw & Upgd Bay
302,564
97
Crenshaw: Add Circuit Switcher
163,217
98
EML C Spire - Northern Route
404,398
99
EML: 115-13.8 | 20MVA (Marvell)
254,181
100
EML:115-4.16 | 12.5MVA | JTreatment
297,538
101
Fannin Rd: add Fdr Bkr Amp Transduc
341,192
102
Florence: Capacitors (54) on CapBk
120,841
103
Franklin 500kV Reconfiguration
8,127,763
104
Franklin: AT1 Cph/Spare Life Extend
431,407
105
Gallatin: rpl FX20 & add FX10 Fdr
187,994
106
GGNS: E&D ST-21 Xfmr Bay Upgd
457,530
107
Greenville Replace Breaker 3E08, J4
289,280
108
Greenville SE Install circuit sw. o
248,340
109
Hazlehurst add circuit switchers
508,806
110
Hollandale: E&D 3J22 & 02 Bkr Rpl
101,258
111
Indianola: E&D J3110 Xfmr Bay Upgd
928,031
112
Jackson, S: E&D J4674 Bay Upgrade
230,453
113
Jackson, W: rpl RTU
125,885
114
Johns-Manville: E&D J0467 Bay Upgd
514,317
115
Midnight: rpl ABS J0348 & Steel Bus
154,507
116
Northpark: Add 230/115kV-400MVA Aut
1,361,921
117
Pickens replace breaker J1708, line
292,045
118
Raleigh 115kV Sub - Add 2nd Transf
450,221
119
Rankin 115kV Sub - Add Line Bay
169,517
120
Schlater 115kV Station: Add Brkrs
4,121,815
121
Snowden Park-Bld 115kV Sub-Scoping
1,754,944
122
Whitfield: add Ckt Sw, rpl T1 Diff
135,330
123
Yandell Sub Upgrades
437,255
124
Other transmission and distribution substation plant
1,470,048
125
Bowling Green - Durant 115kV CAP
136,431
126
C6PPTM2110: Brookhaven - Wesson 115
1,063,976
127
E. Vicksburg-E. Vicksburg 115kV CAP
117,870
128
Franklin-GGNS 500Kv Phase Swa
305,628
129
Getwell-Twinkletown 230kV Cut-In
602,482
130
Greenbrook to Snowden Park 115kv Ln
120,765
131
Greenville TCEPA - Arcola 115kV CAP
228,884
132
Greenwood-Itta Bena 115Kv Cut-In
158,883
133
Indianola-Itta Bena 115kv
318,834
134
Lakeover-Hinds 230kV CAP
283,116
135
Pelahatchie - Rankin 115kV CAP
165,632
136
Other transmission lines plant
210,043
137
Undistributed overhead
630,732
43 Total
95,935,092


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
ACCUMULATED PROVISION FOR DEPRECIATION OF ELECTRIC UTILITY PLANT (Account 108)
  1. Explain in a footnote any important adjustments during year.
  2. Explain in a footnote any difference between the amount for book cost of plant retired, Line 12, column (c), and that reported for electric plant in service, page 204, column (d), excluding retirements of non-depreciable property.
  3. The provisions of Account 108 in the Uniform System of Accounts require that retirements of depreciable plant be recorded when such plant is removed from service. If the respondent has a significant amount of plant retired at year end which has not been recorded and/or classified to the various reserve functional classifications, make preliminary closing entries to tentatively functionalize the book cost of the plant retired. In addition, include all costs included in retirement work in progress at year end in the appropriate functional classifications.
  4. Show separately interest credits under a sinking fund or similar method of depreciation accounting.
Line No.
Item
(a)
Total (c + d + e)
(b)
Electric Plant in Service
(c)
Electric Plant Held for Future Use
(d)
Electric Plant Leased To Others
(e)
Section A. Balances and Changes During Year
1
AccumulatedProvisionForDepreciationOfElectricUtilityPlant
Balance Beginning of Year
1,687,320,379
1,687,313,571
6,808
2
Depreciation Provisions for Year, Charged to
3
DepreciationExpenseExcludingAdjustments
(403) Depreciation Expense
199,709,644
(a)
199,709,644
4
DepreciationExpenseForAssetRetirementCosts
(403.1) Depreciation Expense for Asset Retirement Costs
11,486
11,486
5
ExpensesOfElectricPlantLeasedToOthers
(413) Exp. of Elec. Plt. Leas. to Others
6
TransportationExpensesClearing
Transportation Expenses-Clearing
7
OtherClearingAccounts
Other Clearing Accounts
8
OtherAccounts
Other Accounts (Specify, details in footnote):
9.1
Other Accounts (Specify, details in footnote):
17,858
(b)
17,858
10
DepreciationProvision
TOTAL Deprec. Prov for Year (Enter Total of lines 3 thru 9)
199,738,988
199,738,988
11
Net Charges for Plant Retired:
12
BookCostOfRetiredPlant
Book Cost of Plant Retired
74,320,590
(c)
74,320,590
13
CostOfRemovalOfPlant
Cost of Removal
58,585,284
58,585,284
14
SalvageValueOfRetiredPlant
Salvage (Credit)
3,255,287
3,255,287
15
NetChargesForRetiredPlant
TOTAL Net Chrgs. for Plant Ret. (Enter Total of lines 12 thru 14)
129,650,587
129,650,587
16
OtherAdjustmentsToAccumulatedDepreciation
Other Debit or Cr. Items (Describe, details in footnote):
17.1
Other Debit or Cr. Items (Describe, details in footnote):
95,012
(d)
95,012
18
BookCostOfAssetRetirementCosts
Book Cost or Asset Retirement Costs Retired
19
AccumulatedProvisionForDepreciationOfElectricUtilityPlant
Balance End of Year (Enter Totals of lines 1, 10, 15, 16, and 18)
1,757,313,768
1,757,306,960
6,808
Section B. Balances at End of Year According to Functional Classification
20
AccumulatedDepreciationSteamProduction
Steam Production
396,439,449
396,437,064
2,385
21
AccumulatedDepreciationNuclearProduction
Nuclear Production
22
AccumulatedDepreciationHydraulicProductionConventional
Hydraulic Production-Conventional
23
AccumulatedDepreciationHydraulicProductionPumpedStorage
Hydraulic Production-Pumped Storage
24
AccumulatedDepreciationOtherProduction
Other Production
365,623,550
365,623,550
25
AccumulatedDepreciationTransmission
Transmission
438,853,295
438,848,872
4,423
26
AccumulatedDepreciationDistribution
Distribution
533,623,234
533,623,234
27
AccumulatedDepreciationRegionalTransmissionAndMarketOperation
Regional Transmission and Market Operation
28
AccumulatedDepreciationGeneral
General
22,774,240
22,774,240
29
AccumulatedProvisionForDepreciationOfElectricUtilityPlant
TOTAL (Enter Total of lines 20 thru 28)
1,757,313,768
1,757,306,960
6,808


FOOTNOTE DATA

(a) Concept: DepreciationExpenseExcludingAdjustments
Excludes service company depreciation allocations of $3,207,942 (included in the depreciation expense shown on page 336), since these allocations do not offset to accumulated reserves.
(b) Concept: OtherAccounts
Includes depreciation on Gerald Andrus pipelines and Independence, which is accounted for as fuel expense.
(c) Concept: BookCostOfRetiredPlant
Excludes retirements of $58,969 (included in Amortization of Other Utility Plant shown on pages 204 - 207), since these retirements do not offset to accumulated depreciation reserves.
(d) Concept: OtherAdjustmentsToAccumulatedDepreciation
Sale of Land - Nesbit ($14,912)
Sale of Land - Plum Point (80,275)
Sale of Land - Tillatoba 175 
Total ($95,012)

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
INVESTMENTS IN SUBSIDIARY COMPANIES (Account 123.1)
  1. Report below investments in Account 123.1, Investments in Subsidiary Companies.
  2. Provide a subheading for each company and list thereunder the information called for below. Sub-TOTAL by company and give a TOTAL in columns (e), (f), (g) and (h). (a) Investment in Securities - List and describe each security owned. For bonds give also principal amount, date of issue, maturity, and interest rate. (b) Investment Advances - Report separately the amounts of loans or investment advances which are subject to repayment, but which are not subject to current settlement. With respect to each advance show whether the advance is a note or open account. List each note giving date of issuance, maturity date, and specifying whether note is a renewal.
  3. Report separately the equity in undistributed subsidiary earnings since acquisition. The TOTAL in column (e) should equal the amount entered for Account 418.1.
  4. For any securities, notes, or accounts that were pledged designate such securities, notes, or accounts in a footnote, and state the name of pledgee and purpose of the pledge.
  5. If Commission approval was required for any advance made or security acquired, designate such fact in a footnote and give name of Commission, date of authorization, and case or docket number.
  6. Report column (f) interest and dividend revenues from investments, including such revenues from securities disposed of during the year.
  7. In column (h) report for each investment disposed of during the year, the gain or loss represented by the difference between cost of the investment (or the other amount at which carried in the books of account if different from cost) and the selling price thereof, not including interest adjustment includible in column (f).
  8. Report on Line 42, column (a) the TOTAL cost of Account 123.1.
Line No.
DescriptionOfInvestmentsInSubsidiaryCompanies
Description of Investment
(a)
DateOfAcquisitionInvestmentsInSubsidiaryCompanies
Date Acquired
(b)
DateOfMaturityInvestmentsInSubsidiaryCompanies
Date of Maturity
(c)
InvestmentInSubsidiaryCompanies
Amount of Investment at Beginning of Year
(d)
EquityInEarningsOfSubsidiaryCompanies
Equity in Subsidiary Earnings of Year
(e)
InterestAndDividendRevenueFromInvestments
Revenues for Year
(f)
InvestmentInSubsidiaryCompanies
Amount of Investment at End of Year
(g)
InvestmentGainLossOnDisplosal
Gain or Loss from Investment Disposed of
(h)
1
EMI New Nuclear, LLC - Subsidiary Company Subheading
09/18/2008
2
EMI New Nuclear, LLC - Capital Contribution
14,000
8,305
5,695
3
EMI New Nuclear, LLC - Unappropriated Undistributed Subsidiary Earnings
3,695
3,695
4
EMI New Nuclear, LLC - Subtotal
10,305
8,305
2,000
5
Mississippi Power & Light Co. - Subsidiary Company Subheading
6
Mississippi Power & Light Co. - Capital Contribution
517
517
7
Mississippi Power & Light Co. - Unappropriated Undistributed Subsidiary Earnings
275
275
8
Mississippi Power & Light Co. - Subtotal
242
242
42
Total Cost of Account 123.1 $
Total
10,547
8,305
2,242


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
MATERIALS AND SUPPLIES
  1. For Account 154, report the amount of plant materials and operating supplies under the primary functional classifications as indicated in column (a); estimates of amounts by function are acceptable. In column (d), designate the department or departments which use the class of material.
  2. Give an explanation of important inventory adjustments during the year (in a footnote) showing general classes of material and supplies and the various accounts (operating expenses, clearing accounts, plant, etc.) affected debited or credited. Show separately debit or credits to stores expense clearing, if applicable.
Line No.
Account
(a)
Balance Beginning of Year
(b)
Balance End of Year
(c)
Department or Departments which Use Material
(d)
1
Fuel Stock (Account 151)
17,004,333
10,290,914
2
Fuel Stock Expenses Undistributed (Account 152)
66,020
3
Residuals and Extracted Products (Account 153)
4
Plant Materials and Operating Supplies (Account 154)
5
Assigned to - Construction (Estimated)
(a)
41,356,038
(b)
56,438,756
Electric
6
Assigned to - Operations and Maintenance
7
Production Plant (Estimated)
13,580,542
8,799,360
Electric
8
Transmission Plant (Estimated)
74,584
112,746
Electric
9
Distribution Plant (Estimated)
549,370
777,069
Electric
10
Regional Transmission and Market Operation Plant (Estimated)
11
Assigned to - Other (provide details in footnote)
12
TOTAL Account 154 (Enter Total of lines 5 thru 11)
55,560,534
66,127,931
13
Merchandise (Account 155)
14
Other Materials and Supplies (Account 156)
15
Nuclear Materials Held for Sale (Account 157) (Not applic to Gas Util)
16
Stores Expense Undistributed (Account 163)
3,981,225
3,510,746
17
18
19
20
TOTAL Materials and Supplies
76,612,112
79,929,591


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
FOOTNOTE DATA

(a) Concept: PlantMaterialsAndOperatingSuppliesConstruction
BALANCE AT
BEG OF YEAR
Production (estimated) $21,944,092 
Transmission (estimated) 3,756,915 
Distribution (estimated) 15,655,031 
Total Assigned to Construction (estimated) $41,356,038 
(b) Concept: PlantMaterialsAndOperatingSuppliesConstruction
BALANCE AT
 END OF YEAR
Production (estimated) $29,883,419 
Transmission (estimated) 6,207,344 
Distribution (estimated) 20,347,993 
Total Assigned to Construction (estimated) $56,438,756 

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
Allowances (Accounts 158.1 and 158.2)
  1. Report below the particulars (details) called for concerning allowances.
  2. Report all acquisitions of allowances at cost.
  3. Report allowances in accordance with a weighted average cost allocation method and other accounting as prescribed by General Instruction No. 21 in the Uniform System of Accounts.
  4. Report the allowances transactions by the period they are first eligible for use: the current year’s allowances in columns (b)-(c), allowances for the three succeeding years in columns (d)-(i), starting with the following year, and allowances for the remaining succeeding years in columns (j)-(k).
  5. Report on Line 4 the Environmental Protection Agency (EPA) issued allowances. Report withheld portions Lines 36-40.
  6. Report on Line 5 allowances returned by the EPA. Report on Line 39 the EPA’s sales of the withheld allowances. Report on Lines 43-46 the net sales proceeds and gains/losses resulting from the EPA’s sale or auction of the withheld allowances.
  7. Report on Lines 8-14 the names of vendors/transferors of allowances acquired and identify associated companies (See "associated company" under "Definitions" in the Uniform System of Accounts).
  8. Report on Lines 22 - 27 the name of purchasers/ transferees of allowances disposed of and identify associated companies.
  9. Report the net costs and benefits of hedging transactions on a separate line under purchases/transfers and sales/transfers.
  10. Report on Lines 32-35 and 43-46 the net sales proceeds and gains or losses from allowance sales.
Current Year Year One Year Two Year Three Future Years Totals
Line No.
SO2 Allowances Inventory (Account 158.1)
(a)
No.
(b)
Amt.
(c)
No.
(d)
Amt.
(e)
No.
(f)
Amt.
(g)
No.
(h)
Amt.
(i)
No.
(j)
Amt.
(k)
No.
(l)
Amt.
(m)
1
Balance-Beginning of Year
150,710
150,710
2
3
Acquired During Year:
4
Issued (Less Withheld Allow)
15,931
15,930
15,930
15,930
(a)
446,047
509,768
0
5
Returned by EPA
6
7
8
Purchases/Transfers:
75
75
9
10
11
12
13
14
15
Total
75
75
16
17
Relinquished During Year:
18
Charges to Account 509
19
Other:
20
Allowances Used
20.1
Allowances Used
21
Cost of Sales/Transfers:
22
Compliance Deduction
2,787
2,787
23
24
25
26
27
28
Total
2,787
2,787
29
Balance-End of Year
163,929
15,930
15,930
15,930
446,047
657,766
30
31
Sales:
32
Net Sales Proceeds(Assoc. Co.)
33
Net Sales Proceeds (Other)
34
Gains
35
Losses
Allowances Withheld (Acct 158.2)
36
Balance-Beginning of Year
37
Add: Withheld by EPA
38
Deduct: Returned by EPA
39
Cost of Sales
40
Balance-End of Year
41
42
Sales
43
Net Sales Proceeds (Assoc. Co.)
44
Net Sales Proceeds (Other)
45
Gains
46
Losses


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
FOOTNOTE DATA

(a) Concept: AllowancesIssuedLessWithheldAllowancesNumber
Future years include allowances issued from 2025 through 2052.

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
Allowances (Accounts 158.1 and 158.2)
  1. Report below the particulars (details) called for concerning allowances.
  2. Report all acquisitions of allowances at cost.
  3. Report allowances in accordance with a weighted average cost allocation method and other accounting as prescribed by General Instruction No. 21 in the Uniform System of Accounts.
  4. Report the allowances transactions by the period they are first eligible for use: the current year’s allowances in columns (b)-(c), allowances for the three succeeding years in columns (d)-(i), starting with the following year, and allowances for the remaining succeeding years in columns (j)-(k).
  5. Report on Line 4 the Environmental Protection Agency (EPA) issued allowances. Report withheld portions Lines 36-40.
  6. Report on Line 5 allowances returned by the EPA. Report on Line 39 the EPA’s sales of the withheld allowances. Report on Lines 43-46 the net sales proceeds and gains/losses resulting from the EPA’s sale or auction of the withheld allowances.
  7. Report on Lines 8-14 the names of vendors/transferors of allowances acquired and identify associated companies (See "associated company" under "Definitions" in the Uniform System of Accounts).
  8. Report on Lines 22 - 27 the name of purchasers/ transferees of allowances disposed of and identify associated companies.
  9. Report the net costs and benefits of hedging transactions on a separate line under purchases/transfers and sales/transfers.
  10. Report on Lines 32-35 and 43-46 the net sales proceeds and gains or losses from allowance sales.
Current Year Year One Year Two Year Three Future Years Totals
Line No.
NOx Allowances Inventory (Account 158.1)
(a)
No.
(b)
Amt.
(c)
No.
(d)
Amt.
(e)
No.
(f)
Amt.
(g)
No.
(h)
Amt.
(i)
No.
(j)
Amt.
(k)
No.
(l)
Amt.
(m)
1
Balance-Beginning of Year
154
46,554
154
46,554
2
3
Acquired During Year:
4
Issued (Less Withheld Allow)
2,316
2,267
2,267
2,267
(a)
4,534
13,651
5
Returned by EPA
92
92
6
7
8
Purchases/Transfers:
9
Current Period Adjustment
10
11
12
13
14
15
Total
16
17
Relinquished During Year:
18
Charges to Account 509
1,437
26,384
1,437
26,384
19
Other:
20
Allowances Used
20.1
Allowances Used
21
Cost of Sales/Transfers:
22
23
24
25
26
27
28
Total
29
Balance-End of Year
1,125
20,170
2,267
2,267
2,267
4,534
12,460
20,170
30
31
Sales:
32
Net Sales Proceeds(Assoc. Co.)
33
Net Sales Proceeds (Other)
34
Gains
35
Losses
Allowances Withheld (Acct 158.2)
36
Balance-Beginning of Year
37
Add: Withheld by EPA
38
Deduct: Returned by EPA
39
Cost of Sales
40
Balance-End of Year
41
42
Sales
43
Net Sales Proceeds (Assoc. Co.)
44
Net Sales Proceeds (Other)
45
Gains
46
Losses


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
FOOTNOTE DATA

(a) Concept: AllowancesIssuedLessWithheldAllowancesNumber
Future years include allowances issued from 2025 through 2026.

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
EXTRAORDINARY PROPERTY LOSSES (Account 182.1)
WRITTEN OFF DURING YEAR
Line No.
DescriptionOfExtraordinaryPropertyLoss
Description of Extraordinary Loss [Include in the description the date of Commission Authorization to use Acc 182.1 and period of amortization (mo, yr to mo, yr).]
(a)
ExtraordinaryPropertyLossesNotYetRecognized
Total Amount of Loss
(b)
ExtraordinaryPropertyLossesRecognized
Losses Recognized During Year
(c)
ExtraordinaryPropertyLossesWrittenOffAccountCharged
Account Charged
(d)
ExtraordinaryPropertyLossesWrittenOff
Amount
(e)
ExtraordinaryPropertyLosses
Balance at End of Year
(f)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
20 TOTAL


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
UNRECOVERED PLANT AND REGULATORY STUDY COSTS (182.2)
WRITTEN OFF DURING YEAR
Line No.
DescriptionOfUnrecoveredPlantAndRegulatoryStudyCosts
Description of Unrecovered Plant and Regulatory Study Costs [Include in the description of costs, the date of COmmission Authorization to use Acc 182.2 and period of amortization (mo, yr to mo, yr)]
(a)
UnrecoveredPlantAndRegulatoryStudyCostsNotYetRecognized
Total Amount of Charges
(b)
UnrecoveredPlantAndRegulatoryStudyCostsRecognized
Costs Recognized During Year
(c)
UnrecoveredPlantAndRegulatoryStudyCostsWrittenOffAccountCharged
Account Charged
(d)
UnrecoveredPlantAndRegulatoryStudyCostsWrittenOff
Amount
(e)
UnrecoveredPlantAndRegulatoryStudyCosts
Balance at End of Year
(f)
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47
48
49
TOTAL


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
Transmission Service and Generation Interconnection Study Costs
  1. Report the particulars (details) called for concerning the costs incurred and the reimbursements received for performing transmission service and generator interconnection studies.
  2. List each study separately.
  3. In column (a) provide the name of the study.
  4. In column (b) report the cost incurred to perform the study at the end of period.
  5. In column (c) report the account charged with the cost of the study.
  6. In column (d) report the amounts received for reimbursement of the study costs at end of period.
  7. In column (e) report the account credited with the reimbursement received for performing the study.
Line No.
DescriptionOfStudyPerformed
Description
(a)
StudyCostsIncurred
Costs Incurred During Period
(b)
StudyCostsAccountCharged
Account Charged
(c)
StudyCostsReimbursements
Reimbursements Received During the Period
(d)
StudyCostsAccountReimbursed
Account Credited With Reimbursement
(e)
1
Transmission Studies
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
Total
21
Generation Studies
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
Total
40 Grand Total


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
OTHER REGULATORY ASSETS (Account 182.3)
  1. Report below the particulars (details) called for concerning other regulatory assets, including rate order docket number, if applicable.
  2. Minor items (5% of the Balance in Account 182.3 at end of period, or amounts less than $100,000 which ever is less), may be grouped by classes.
  3. For Regulatory Assets being amortized, show period of amortization.
CREDITS
Line No.
DescriptionAndPurposeOfOtherRegulatoryAssets
Description and Purpose of Other Regulatory Assets
(a)
OtherRegulatoryAssets
Balance at Beginning of Current Quarter/Year
(b)
IncreaseDecreaseInOtherRegulatoryAssets
Debits
(c)
OtherRegulatoryAssetsWrittenOffAccountCharged
Written off During Quarter/Year Account Charged
(d)
OtherRegulatoryAssetsWrittenOffRecovered
Written off During the Period Amount
(e)
OtherRegulatoryAssets
Balance at end of Current Quarter/Year
(f)
1
Derivative Instruments and Hedging Activities
5,020,445
1,688,919
6,709,364
2
MISO Financial Transmission Rights Mark-to-Market
402,585
402,585
3
Asset Retirement Obligation - Fossil
7,428,685
453,828
7,882,513
4
Asset Retirement Obligation - Coal
425,824
110,210
536,034
5
Defined Benefit Pension & Other Post Retirement Plans
240,456,058
68,271,508
172,184,550
6
Qualified Pension Settlement Cost Deferral MPSC Docket No. 2020-UA-91 Amort 130 months beg Oct 2020
2,029,884
191,799
1,838,085
7
Qualified Pension Settlement Cost Deferral MPSC Docket No. 2020-UA-91 Amort 120 months beg July 2021
12,364,120
367,410
11,996,710
8
Deferred Attorney General Litigation Costs MPSC Docket No. 2009-UN-388 Amort 6 years beg April 2020
25,336,744
4,826,046
20,510,698
9
Deferred Electric Storm Restoration Costs
5,760,571
5,760,571
10
Formula Rate Plan 2021 Settlement MPSC Docket No. 2018-UN-205 Amort 12 months beg June 2021
17,669,553
10,251,831
7,417,722
11
Electric Deferred Fuel Under-Recovery
121,878,218
121,878,218
12
Energy Efficiency Rider Under-Recovery
2,379,841
9,736,122
12,115,963
13
Restructuring Credit Rider Under-Recovery MPSC Docket No. 2018-UA-39
155,410
274,806
430,216
14
Power Management Rider Under-Recovery MPSC Docket No. 2014-UN-132
6,837,754
6,837,754
15
Ad Valorem Tax Adjustment Rider MPSC Docket No. 2014-UN-132
27,980,280
617,165
27,363,115
16
Vegetation Management Rider MPSC Docket No. 2018-UN-205
7,061,164
6,332,770
728,394
17
Deferred COVID-19 costs MPSC Docket No. 2018-AD-141 - Amort July 2021-June 2022
19,219,538
4,247,992
14,971,546
18
Choctaw Generating Station Under-Recovery MPSC Docket No. 2018-UN-205 - Amort April 2021-March 2022
1,147,559
717,224
430,335
19
Income Taxes
25,118,080
25,118,080
20
Formula Rate Plan Revenue Increase MPSC Docket No. 2018-UN-205
19,000,000
19,000,000
44
TOTAL
344,331,627
215,604,571
102,661,499
457,274,699


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
MISCELLANEOUS DEFFERED DEBITS (Account 186)
  1. Report below the particulars (details) called for concerning miscellaneous deferred debits.
  2. For any deferred debit being amortized, show period of amortization in column (a)
  3. Minor item (1% of the Balance at End of Year for Account 186 or amounts less than $100,000, whichever is less) may be grouped by classes.
CREDITS
Line No.
Description of Miscellaneous Deferred Debits
(a)
Balance at Beginning of Year
(b)
Debits
(c)
Credits Account Charged
(d)
Credits Amount
(e)
Balance at End of Year
(f)
1
ISES Acquisition Adjustment
356,400
178,200
178,200
2
Non-Expense Accrued Labor
1,885,170
128,576
2,013,746
3
Section 263A
125,611
15,701
109,910
4
Mark-to-Market
14,569
1,325
13,244
47
Miscellaneous Work in Progress
48
Deferred Regulatroy Comm. Expenses (See pages 350 - 351)
49
TOTAL
2,381,750
2,315,100


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
ACCUMULATED DEFERRED INCOME TAXES (Account 190)
  1. Report the information called for below concerning the respondent’s accounting for deferred income taxes.
  2. At Other (Specify), include deferrals relating to other income and deductions.
Line No.
DescriptionOfAccumulatedDeferredIncomeTax
Description and Location
(a)
AccumulatedDeferredIncomeTaxes
Balance at Beginning of Year
(b)
AccumulatedDeferredIncomeTaxes
Balance at End of Year
(c)
1
Electric
2
(a)
See Footnote
604,138,349
607,243,412
7
Other
8
TOTAL Electric (Enter Total of lines 2 thru 7)
604,138,349
607,243,412
9
Gas
15
Other
16
TOTAL Gas (Enter Total of lines 10 thru 15)
17.1
Other (Specify)
17
Other (Specify)
18
TOTAL (Acct 190) (Total of lines 8, 16 and 17)
604,138,349
607,243,412
Notes


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
FOOTNOTE DATA

(a) Concept: DescriptionOfAccumulatedDeferredIncomeTax
BALANCE AT BEG OF YEAR BALANCE AT END OF YEAR
Abandonment Loss $1,425,680  $1,425,680 
Intrst/Tax Tax Deficiencies 324,350  324,350 
Taxable Unbilled Revenue 2,989,037  2,306,012 
Property Insurance Reserve 10,192,222  6,842,571 
Capitalized Repairs 514,987  343,363 
Injuries & Damages Reserve 1,306,620  1,104,343 
Contribution in Aid of Construction 8,486,129  8,597,766 
Pension Plan (25,444,365) (22,836,428)
Defined Benefit Pension 58,488,326  41,545,899 
Supplemental Pension Plan 522,485  583,765 
Other Post Employment Benefits (7,554,867) (8,530,942)
Deferred Fuel (1,706,019)
Removal Cost (15,765,717) (25,244,903)
Accrual of Reserves —  15,974 
Asset Retirement Obligation 1,006  1,006 
Litigation Settlement —  62,375 
Accrued Medical Claims 791,730  738,291 
Uncollectible Accounts 4,871,921  1,798,671 
Def Gain/Basis Step-Up 259,176  215,142 
Basis Step-Up 4,414,175  3,209,109 
Regulatory Liability (4,584,563) (3,461,813)
Partnership Income/Loss 22,979  2,052 
Contract Deferred Revenue 26,586  55,866 
Lease - Rental Expense 59,445  93,946 
Environmental Reserve 103,792  103,792 
Incentive Compensation 1,400,984  1,880,868 
Long-Term Incentive Compensation 70,734  76,358 
Stock Options 11,207  23,748 
Restricted Stock Awards 187,065  200,207 
Rate Refund 134,231  — 
Transition Costs 601,468  300,735 
Payroll Tax Accruals 453,393  — 
Income tax adjustment 58,149,032  61,994,672 
Tax Attribute - NOL/CR Carryforward 6,774,083  2,509,371 
ADIT-NOL-SRLY Fed NonCur 356,504,820  280,290,570 
ADIT-Tax CR Carryforward 1,278,623  3,322,111 
Fed Offset-St Carryover (22,630,606) (24,464,775)
ADIT NOL Carryforward 159,465,950  269,786,591 
ADIT-Ben-Potnt Disall UTPs Res 1,992,250  2,027,068 
TOTAL $604,138,349  $607,243,412 

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
CAPITAL STOCKS (Account 201 and 204)
  1. Report below the particulars (details) called for concerning common and preferred stock at end of year, distinguishing separate series of any general class. Show separate totals for common and preferred stock. If information to meet the stock exchange reporting requirement outlined in column (a) is available from the SEC 10-K Report Form filing, a specific reference to report form (i.e., year and company title) may be reported in column (a) provided the fiscal years for both the 10-K report and this report are compatible.
  2. Entries in column (b) should represent the number of shares authorized by the articles of incorporation as amended to end of year.
  3. Give details concerning shares of any class and series of stock authorized to be issued by a regulatory commission which have not yet been issued.
  4. The identification of each class of preferred stock should show the dividend rate and whether the dividends are cumulative or noncumulative.
  5. State in a footnote if any capital stock that has been nominally issued is nominally outstanding at end of year.
  6. Give particulars (details) in column (a) of any nominally issued capital stock, reacquired stock, or stock in sinking and other funds which is pledged, stating name of pledgee and purpose of pledge.
Line No.
Class and Series of Stock and Name of Stock Series
(a)
Number of Shares Authorized by Charter
(b)
Par or Stated Value per Share
(c)
Call Price at End of Year
(d)
Outstanding per Bal. Sheet (Total amount outstanding without reduction for amounts held by respondent) Shares
(e)
Outstanding per Bal. Sheet (Total amount outstanding without reduction for amounts held by respondent) Amount
(f)
Held by Respondent As Reacquired Stock (Acct 217) Shares
(g)
Held by Respondent As Reacquired Stock (Acct 217) Cost
(h)
Held by Respondent In Sinking and Other Funds Shares
(i)
Held by Respondent In Sinking and Other Funds Amount
(j)
1
Common Stock (Account 201)
2
3
4
5
Total
6
Preferred Stock (Account 204)
7
8
9
10
Total
1
Capital Stock (Accounts 201 and 204) - Data Conversion
2
3
4
5
Total


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

2022-04-15
Year/Period of Report

End of:
2021
/
Q4
Other Paid-in Capital
1. Report below the balance at the end of the year and the information specified below for the respective other paid-in capital accounts. Provide a subheading for each account and show a total for the account, as well as a total of all accounts for reconciliation with the balance sheet, page 112. Explain changes made in any account during the year and give the accounting entries effecting such change.
  1. Donations Received from Stockholders (Account 208) - State amount and briefly explain the origin and purpose of each donation.
  2. Reduction in Par or Stated Value of Capital Stock (Account 209) - State amount and briefly explain the capital changes that gave rise to amounts reported under this caption including identification with the class and series of stock to which related.
  3. Gain or Resale or Cancellation of Reacquired Capital Stock (Account 210) - Report balance at beginning of year, credits, debits, and balance at end of year with a designation of the nature of each credit and debit identified by the class and series of stock to which related.
  4. Miscellaneous Paid-In Capital (Account 211) - Classify amounts included in this account according to captions that, together with brief explanations, disclose the general nature of the transactions that gave rise to the reported amounts.
Line No.
Item
(a)
Amount
(b)
1
DonationsReceivedFromStockholdersAbstract
Donations Received from Stockholders (Account 208)
2
DonationsReceivedFromStockholders
Beginning Balance Amount
3.1
IncreasesDecreasesFromSalesOfDonationsReceivedFromStockholders
Increases (Decreases) from Sales of Donations Received from Stockholders
4
DonationsReceivedFromStockholders
Ending Balance Amount
5
ReductionInParOrStatedValueOfCapitalStockAbstract
Reduction in Par or Stated Value of Capital Stock (Account 209)
6
ReductionInParOrStatedValueOfCapitalStock
Beginning Balance Amount
7.1
IncreasesDecreasesDueToReductionsInParOrStatedValueOfCapitalStock
Increases (Decreases) Due to Reductions in Par or Stated Value of Capital Stock
8
ReductionInParOrStatedValueOfCapitalStock
Ending Balance Amount
9
GainOrResaleOrCancellationOfReacquiredCapitalStockAbstract
Gain or Resale or Cancellation of Reacquired Capital Stock (Account 210)
10
GainOnResaleOrCancellationOfReacquiredCapitalStock
Beginning Balance Amount
11.1
IncreasesDecreasesFromGainOrResaleOrCancellationOfReacquiredCapitalStock
Increases (Decreases) from Gain or Resale or Cancellation of Reacquired Capital Stock
12
GainOnResaleOrCancellationOfReacquiredCapitalStock
Ending Balance Amount
13
MiscellaneousPaidInCapitalAbstract
Miscellaneous Paid-In Capital (Account 211)
14
MiscellaneousPaidInCapital
Beginning Balance Amount
329,266,361
15.1
IncreasesDecreasesDueToMiscellaneousPaidInCapital
Increases (Decreases) Due to Miscellaneous Paid-In Capital
16
MiscellaneousPaidInCapital
Ending Balance Amount
329,266,361
17
OtherPaidInCapitalAbstract
Historical Data - Other Paid in Capital
18
OtherPaidInCapitalDetail
Beginning Balance Amount
19.1
IncreasesDecreasesInOtherPaidInCapital
Increases (Decreases) in Other Paid-In Capital
20
OtherPaidInCapitalDetail
Ending Balance Amount
40
OtherPaidInCapital
Total
329,266,361


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
CAPITAL STOCK EXPENSE (Account 214)
  1. Report the balance at end of the year of discount on capital stock for each class and series of capital stock.
  2. If any change occurred during the year in the balance in respect to any class or series of stock, attach a statement giving particulars (details) of the change. State the reason for any charge-off of capital stock expense and specify the account charged.
Line No.
NameOfClassAndSeriesOfStock
Class and Series of Stock
(a)
CapitalStockExpense
Balance at End of Year
(b)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
TOTAL


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
LONG-TERM DEBT (Account 221, 222, 223 and 224)
  1. Report by Balance Sheet Account the details concerning long-term debt included in Accounts 221, Bonds, 222, Reacquired Bonds, 223, Advances from Associated Companies, and 224, Other Long-Term Debt.
  2. For bonds assumed by the respondent, include in column (a) the name of the issuing company as well as a description of the bonds, and in column (b) include the related account number.
  3. For Advances from Associated Companies, report separately advances on notes and advances on open accounts. Designate demand notes as such. Include in column (a) names of associated companies from which advances were received, and in column (b) include the related account number.
  4. For receivers' certificates, show in column (a) the name of the court and date of court order under which such certificates were issued, and in column (b) include the related account number.
  5. In a supplemental statement, give explanatory details for Accounts 223 and 224 of net changes during the year. With respect to long-term advances, show for each company: (a)principal advanced during year (b) interest added to principal amount, and (c) principal repaid during year. Give Commission authorization numbers and dates.
  6. If the respondent has pledged any of its long-term debt securities, give particulars (details) in a footnote, including name of the pledgee and purpose of the pledge.
  7. If the respondent has any long-term securities that have been nominally issued and are nominally outstanding at end of year, describe such securities in a footnote.
  8. If interest expense was incurred during the year on any obligations retired or reacquired before end of year, include such interest expense in column (m). Explain in a footnote any difference between the total of column (m) and the total Account 427, Interest on Long-Term Debt and Account 430, Interest on Debt to Associated Companies.
  9. Give details concerning any long-term debt authorized by a regulatory commission but not yet issued.
Line No.
ClassAndSeriesOfObligationCouponRateDescription
Class and Series of Obligation, Coupon Rate (For new issue, give commission Authorization numbers and dates)
(a)
RelatedAccountNumber
Related Account Number
(b)
Principal Amount of Debt Issued
(c)
LongTermDebtIssuanceExpensePremiumOrDiscount
Total Expense, Premium or Discount
(d)
LongTermDebtIssuanceExpenses
Total Expense
(e)
LongTermDebtPremium
Total Premium
(f)
LongTermDebtDiscount
Total Discount
(g)
NominalDateOfIssue
Nominal Date of Issue
(h)
DateOfMaturity
Date of Maturity
(i)
AmortizationPeriodStartDate
AMORTIZATION PERIOD Date From
(j)
AmortizationPeriodEndDate
AMORTIZATION PERIOD Date To
(k)
Outstanding (Total amount outstanding without reduction for amounts held by respondent)
(l)
Interest for Year Amount
(m)
1
Bonds (Account 221)
2
3.1% Series
250,000,000
1,992,167
985,000
12/11/2012
07/01/2023
12/11/2012
07/01/2023
250,000,000
7,750,000
3
3.75% Series
100,000,000
954,738
30,000
03/21/2014
07/01/2024
03/21/2014
07/01/2024
100,000,000
3,750,000
4
2.85% Series
375,000,000
2,878,733
120,000
05/13/2016
06/01/2028
05/13/2016
06/01/2028
375,000,000
10,687,500
5
4.9% Series
260,000,000
8,107,064
09/15/2016
10/01/2066
09/15/2016
10/01/2066
260,000,000
12,740,000
6
3.25% Series
150,000,000
1,362,173
511,500
11/14/2017
12/01/2027
11/14/2017
12/01/2027
150,000,000
4,875,000
7
4.52% Series
55,000,000
511,787
12/12/2018
12/01/2038
12/12/2018
12/01/2038
55,000,000
2,486,000
8
3.85% Series 1
300,000,000
3,171,620
3,891,000
06/05/2019
06/01/2049
06/05/2019
06/01/2049
300,000,000
11,550,000
9
3.85% Series 2
135,000,000
1,395,028
10,813,500
11/19/2019
06/01/2049
11/19/2019
06/01/2049
135,000,000
5,197,500
10
3.5% Series 1
170,000,000
2,166,734
2,410,600
05/22/2020
06/01/2051
05/22/2020
06/01/2051
170,000,000
5,950,000
11
3.5% Series 2
200,000,000
2,150,279
2,754,000
03/12/2021
06/01/2051
03/12/2021
06/01/2051
200,000,000
5,619,444
12
2.55% Series
200,000,000
1,748,183
516,000
11/16/2021
12/01/2033
11/16/2021
12/01/2033
200,000,000
637,500
13
Subtotal
2,195,000,000
26,438,506
13,567,500
8,464,100
2,195,000,000
71,242,944
14
Reacquired Bonds (Account 222)
15
16
17
18
Subtotal
19
Advances from Associated Companies (Account 223)
20
21
22
23
Subtotal
24
Other Long Term Debt (Account 224)
25
26
27
28
Subtotal
33 TOTAL
2,195,000,000
2,195,000,000
(a)
71,242,944


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
FOOTNOTE DATA

(a) Concept: InterestExpenseOnLongTermDebtIssued
Total interest for Accounts 221 and 224 is recorded in Account 427, as shown on page 117, line 62.

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
RECONCILIATION OF REPORTED NET INCOME WITH TAXABLE INCOME FOR FEDERAL INCOME TAXES
  1. Report the reconciliation of reported net income for the year with taxable income used in computing Federal income tax accruals and show computation of such tax accruals. Include in the reconciliation, as far as practicable, the same detail as furnished on Schedule M-1 of the tax return for the year. Submit a reconciliation even though there is no taxable income for the year. Indicate clearly the nature of each reconciling amount.
  2. If the utility is a member of a group which files a consolidated Federal tax return, reconcile reported net income with taxable net income as if a separate return were to be field, indicating, however, intercompany amounts to be eliminated in such a consolidated return. State names of group member, tax assigned to each group member, and basis of allocation, assignment, or sharing of the consolidated tax among the group members.
  3. A substitute page, designed to meet a particular need of a company, may be used as Long as the data is consistent and meets the requirements of the above instructions. For electronic reporting purposes complete Line 27 and provide the substitute Page in the context of a footnote.
Line No.
Particulars (Details)
(a)
Amount
(b)
1
Net Income for the Year (Page 117)
166,834,143
2
Reconciling Items for the Year
3
4
Taxable Income Not Reported on Books
5
(a)
See Footnote Detail
8,143,995
9
Deductions Recorded on Books Not Deducted for Return
10
(b)
See Footnote Detail
25,213,726
14
Income Recorded on Books Not Included in Return
15
(c)
See Footnote Detail
4,793,511
19
Deductions on Return Not Charged Against Book Income
20
(d)
See Footnote Detail
337,605,822
21
(e)
Other Reconciling Items - See footnote detail
192,634,921
27
Federal Tax Net Income
28
Show Computation of Tax:
29
Normal and Surtax @ 21%
30
(f)
Estimated Consolidated Income Tax Allocated - See Footnote Detail - applicable for 1/1/21 - 12/31/21


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
FOOTNOTE DATA

(a) Concept: TaxableIncomeNotReportedOnBooksDescription
Taxable Income Not Recorded on Books:
Avoided Cost - Tax Interest $1,221,118 
Contributions in Aid of Construction 4,904,814 
Deferred Contract Revenue 255,636 
Obligation for Customer Credits 4,500,000 
Unbilled Revenue (2,737,573)
Total $8,143,995 
(b) Concept: DeductionsRecordedOnBooksNotDeductedForReturnDescription
Deductions Recorded on Books Not Deducted for Return:
Accrual of Reserves ($15,739,364)
Deferred Compensation and Benefits 2,048,858 
Meals and Entertainment 50,142 
Penalties (9,040)
Political Expenses 753,310 
Reserve for Uncollectible Accounts (12,317,632)
Total ($25,213,726)
(c) Concept: IncomeRecordedOnBooksNotIncludedInReturnDescription
Income Recorded on Books Not Included in Return:
Allowance for Funds Used During Construction $4,793,511 
(d) Concept: DeductionsOnReturnNotChargedAgainstBookIncomeDescription
Deductions on Return Not Charged Against Book Income:
Amortization of Other Assets $28,270,002 
Amortization of Regulatory Assets (4,247,992)
Bond Reacquisition Loss (1,356,973)
Decommissioning Costs (30,249)
Deferred Compensation & Benefits 52,266 
Deferred Fuel 115,040,463 
Depreciation of Plant Assets 188,545,160 
Service Company Billings 1,815,870 
Pension and OPEB (18,185,116)
Prepaid Expenses 695,049 
Research and Development Costs (7,535,194)
Software Costs 5,420,019 
UOP Repairs 29,122,517 
Total $337,605,822 
(e) Concept: DeductionsOnReturnNotChargedAgainstBookIncomeDescription
Reconciling Items for the Year:
Net Operating Loss $147,311,997 
Federal Income Tax Accrual - Prior year (5,868,119)
Investment Tax Credit 1,836,307 
FIN 48 taxes 2,087,553 
Provision for Deferred Income Tax 58,773,258 
State Income Tax Accrual - Prior Year (11,506,075)
Total $192,634,921 
(f) Concept: ComputationOfTaxDescription
The Respondent intends to join in the filing of a consolidated Federal Income Tax Return by Entergy Corporation and Subsidiary Companies for the year ended 2021. The estimated consolidated tax allocable under Entergy and Subsidiary Companies Intercompany Income Tax Allocation Agreement based on the provisions of Securities and Exchange Commission Rule 45(c) follows:
FOOTNOTE DATA
Entergy Utility Property, Inc. $162,000 
Entergy Utility Affiliates, LLC (15,000)
Entergy Utility Assets Holdings, Inc. 904,000 
Entergy Utility Group, Inc. (21,000)
System Energy Resources, Inc. 30,734,000 
Entergy Operations, Inc. (97,000)
Entergy Corporation (36,765,000)
Entergy Solutions LLC (1,000)
Entergy Nuclear New York Investment Company, LLC 1,317,000 
Entergy Nuclear Holding Company #3, LLC (3,543,000)
Entergy Assets Management Company, LLC (3,834,000)
Entergy Northeast Holdings, LLC (18,320,000)
Entergy Power Marketing Holding II, Inc. (108,000)
Entergy Nuclear Power Marketing, LLC 7,248,000 
Entergy Nuclear, Inc. (442,000)
Entergy Nuclear Holding Company #1 (5,454,000)
Entergy Nuclear Operations, Inc. (13,904,000)
Entergy Power Holdings, Inc. 2,991,000 
Entergy TransCo HoldCo, LLC (7,000)
EAM Nelson Holding, LLC 332,000 
Entergy Nighthawk GP, LLC 876,000 
Entergy Power Investment Holding, Inc. 1,962,000 
Entergy Mississippi Turbine Company (16,000)
Entergy Nuclear Holding Company #2 221,000 
Entergy Power, LLC (149,000)
Entergy Enterprises, Inc. (31,000)
Entergy Power Gas Operations, LLC 9,627,000 
Entergy Power Marketing Holding I, Inc. (3,887,000)
Entergy Power Operations U.S., Inc. 166,000 
Entergy Nuclear Palisades, LLC (9,752,000)
EK Holding III, LLC (2,000)
EWO Marketing, LLC (40,000)
Entergy Global, LLC (77,000)
Entergy Ventures, Inc. (80,000)
EUP Holdings, LLC 259,000 
Entergy Technology Company (3,000)
Warren Power, LLC (1,000)
Entergy TransCo Texas, LLC (11,000)
Entergy Services Holding, Inc. (Supplemental Information below) 75,187,000 
Entergy Asset Management, Inc. 4,156,000 
Entergy Investments Holding Company, Inc. (3,000)
EWO Wind II, LLC (19,000)
Entergy Nuclear Indian Point 2, LLC (11,037,000)
Entergy Nuclear Indian Point 3, LLC (12,579,000)
Entergy Finance Company, LLC 51,137,000 
Entergy New Orleans, LLC (6,566,000)
Entergy Utility Holding Company, LLC (Supplemental Information below) (60,440,000)
Morpheus One Holdings, LLC (75,000)
Total $— 
FOOTNOTE DATA

Supplemental Information -Entergy Utility Holding Company, LLC
Entergy Louisiana, LLC ($28,329,000)
Entergy Arkansas, LLC (21,083,000.00)
Entergy Mississippi, LLC (9,614,000.00)
Entergy Utility Holding Company, LLC (1,414,000.00)
Total ($60,440,000)
Supplemental Information -Entergy Services Holdings, Inc
Entergy Services Holdings, Inc. $41,991,000 
Entergy Services, LLC 29,168,000.00 
Entergy Account Services, LLC 4,028,000.00 
Total $75,187,000 

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
TAXES ACCRUED, PREPAID AND CHARGES DURING YEAR
  1. Give particulars (details) of the combined prepaid and accrued tax accounts and show the total taxes charged to operations and other accounts during the year. Do not include gasoline and other sales taxes which have been charged to the accounts to which the taxed material was charged. If the actual, or estimated amounts of such taxes are known, show the amounts in a footnote and designate whether estimated or actual amounts.
  2. Include on this page, taxes paid during the year and charged direct to final accounts, (not charged to prepaid or accrued taxes.) Enter the amounts in both columns (g) and (h). The balancing of this page is not affected by the inclusion of these taxes.
  3. Include in column (g) taxes charged during the year, taxes charged to operations and other accounts through (a) accruals credited to taxes accrued, (b)amounts credited to proportions of prepaid taxes chargeable to current year, and (c) taxes paid and charged direct to operations or accounts other than accrued and prepaid tax accounts.
  4. List the aggregate of each kind of tax in such manner that the total tax for each State and subdivision can readily be ascertained.
  5. If any tax (exclude Federal and State income taxes) covers more than one year, show the required information separately for each tax year, identifying the year in column (d).
  6. Enter all adjustments of the accrued and prepaid tax accounts in column (i) and explain each adjustment in a foot- note. Designate debit adjustments by parentheses.
  7. Do not include on this page entries with respect to deferred income taxes or taxes collected through payroll deductions or otherwise pending transmittal of such taxes to the taxing authority.
  8. Report in columns (l) through (o) how the taxes were distributed. Report in column (o) only the amounts charged to Accounts 408.1 and 409.1 pertaining to electric operations. Report in column (l) the amounts charged to Accounts 408.1 and 409.1 pertaining to other utility departments and amounts charged to Accounts 408.2 and 409.2. Also shown in column (o) the taxes charged to utility plant or other balance sheet accounts.
  9. For any tax apportioned to more than one utility department or account, state in a footnote the basis (necessity) of apportioning such tax.
BALANCE AT BEGINNING OF YEAR BALANCE AT END OF YEAR DISTRIBUTION OF TAXES CHARGED
Line No.
DescriptionOfTaxesAccruedPrepaidAndCharged
Kind of Tax (See Instruction 5)
(a)
TypeOfTax
Type of Tax
(b)
TaxJurisdiction
State
(c)
TaxYear
Tax Year
(d)
TaxesAccrued
Taxes Accrued (Account 236)
(e)
PrepaidTaxes
Prepaid Taxes (Include in Account 165)
(f)
TaxesCharged
Taxes Charged During Year
(g)
TaxesPaid
Taxes Paid During Year
(h)
TaxAdjustments
Adjustments
(i)
TaxesAccrued
Taxes Accrued (Account 236)
(j)
PrepaidTaxes
Prepaid Taxes (Included in Account 165)
(k)
TaxesAccruedPrepaidAndCharged
Electric (Account 408.1, 409.1)
(l)
IncomeTaxesExtraordinaryItems
Extraordinary Items (Account 409.3)
(m)
AdjustmentsToRetainedEarnings
Adjustment to Ret. Earnings (Account 439)
(n)
TaxesIncurredOther
Other
(o)
1
Federal Income Tax
Federal Tax
46,088,400
0
5,675,141
8,257,000
48,670,259
4,115,772
1,559,369
2
FICA
Federal Tax
2,828,961
0
8,166,691
8,355,114
2,640,538
3,040,452
5,126,239
3
Federal Uemployment Tax
Federal Tax
7,942
0
34,872
35,164
8,234
16,695
18,177
4
Federal Excise Tax
Federal Tax
0
0
18,575
18,575
0
0
18,575
0
5
Subtotal Federal Tax
48,909,419
0
2,544,997
151,853
0
51,302,563
0
1,040,050
0
0
3,585,047
6
State Income Tax
State Tax
1,356,115
0
11,662,483
11,415,014
1,108,646
11,271,663
390,820
7
0
0
0
0
8
Subtotal State Tax
1,356,115
0
11,662,483
11,415,014
0
1,108,646
0
11,271,663
0
0
390,820
9
Franchise - City
Local Tax
3,998,836
0
14,762,826
14,566,890
4,194,772
14,762,826
0
10
Subtotal Local Tax
3,998,836
0
14,762,826
14,566,890
0
4,194,772
0
14,762,826
0
0
0
11
Privilege License
Other Taxes
0
60,880
77,369
79,544
0
63,055
77,369
0
12
Regulatory Commission
Other Taxes
0
0
993,657
993,657
0
0
1,987,315
993,658
13
Subtotal Other Tax
0
60,880
1,071,026
1,073,201
0
0
63,055
2,064,684
0
0
993,658
14
Subtotal Property Tax
0
0
0
0
0
0
0
0
0
0
0
15
Subtotal Real Estate Tax
0
0
0
0
0
0
0
0
0
0
0
16
State Unemployment Tax
Unemployment Tax
91,967
0
35,913
37,087
90,793
16,483
19,430
17
Subtotal Unemployment Tax
91,967
0
35,913
37,087
0
90,793
0
16,483
0
0
19,430
18
State Use Tax
Sales And Use Tax
634,179
0
7,620,159
7,197,505
1,056,833
0
7,620,159
19
Subtotal Sales And Use Tax
634,179
0
7,620,159
7,197,505
0
1,056,833
0
0
0
0
7,620,159
20
Entergy Services, LLC
Income Tax
0
0
0
1,550,983
1,550,983
21
Subtotal Income Tax
0
0
0
0
0
0
0
1,550,983
0
0
1,550,983
22
State Excise Tax
Excise Tax
0
0
13,680
13,680
0
13,680
0
23
Subtotal Excise Tax
0
0
13,680
13,680
0
0
0
13,680
0
0
0
24
Subtotal Fuel Tax
0
0
0
0
0
0
0
0
0
0
0
25
Subtotal Federal Insurance Tax
0
0
0
0
0
0
0
0
0
0
0
26
Corporate Franchise Tax-MS
Franchise Tax
0
187,158
4,715,288
5,587,158
0
684,712
4,377,788
337,500
27
Corporate Franchise Tax-AR
Franchise Tax
0
17
0
0
0
17
150
150
28
Subtotal Franchise Tax
0
187,141
4,715,288
5,587,158
0
0
684,729
4,377,938
0
0
337,350
29
Non Income Tax
Miscellaneous Other Tax
1,300,000
0
0
0
1,300,000
0
0
30
Subtotal Miscellaneous Other Tax
1,300,000
0
0
0
0
1,300,000
0
0
0
0
0
31
Subtotal Other Federal Tax
0
0
0
0
0
0
0
0
0
0
0
32
Receipts & Sales
Other State Tax
1,563
0
21,392
20,863
2,092
21,392
0
33
Subtotal Other State Tax
1,563
0
21,392
20,863
0
2,092
0
21,392
0
0
0
34
Subtotal Other Property Tax
0
0
0
0
0
0
0
0
0
0
0
35
Subtotal Other Use Tax
0
0
0
0
0
0
0
0
0
0
0
36
Ad Valorem Tax - MS
Other Ad Valorem Tax
99,912,000
0
86,201,818
87,545,818
98,568,000
83,358,798
2,843,020
37
Ad Valorem Tax - AR
Other Ad Valorem Tax
1,218,937
0
1,230,543
1,221,480
1,228,000
1,230,543
0
38
Subtotal Other Advalorem Tax
101,130,937
0
87,432,361
88,767,298
0
99,796,000
0
84,589,341
0
0
2,843,020
39
Subtotal Other License And Fees Tax
0
0
0
0
0
0
0
0
0
0
0
40
Subtotal Payroll Tax
0
0
0
0
0
0
0
0
0
0
0
41
Subtotal Advalorem Tax
0
0
0
0
0
0
0
0
0
0
0
42
Entergy Services, LLC
Other Allocated Tax
0
0
0
2,789,492
2,789,492
43
Subtotal Other Allocated Tax
0
0
0
0
0
0
0
2,789,492
0
0
2,789,492
44
Subtotal Severance Tax
0
0
0
0
0
0
0
0
0
0
0
45
Subtotal Penalty Tax
0
0
0
0
0
0
0
0
0
0
0
46
Subtotal Other Taxes And Fees
0
0
0
0
0
0
0
0
0
0
0
40
TOTAL
157,423,016
126,261
106,555,159
106,000,521
0
158,851,699
747,784
97,875,106
0
0
8,680,053


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
ACCUMULATED DEFERRED INVESTMENT TAX CREDITS (Account 255)

Report below information applicable to Account 255. Where appropriate, segregate the balances and transactions by utility and nonutility operations. Explain by footnote any correction adjustments to the account balance shown in column (g). Include in column (i) the average period over which the tax credits are amortized.

Deferred for Year Allocations to Current Year's Income
Line No.
Account Subdivisions
(a)
Balance at Beginning of Year
(b)
Account No.
(c)
Amount
(d)
Account No.
(e)
Amount
(f)
Adjustments
(g)
Balance at End of Year
(h)
Average Period of Allocation to Income
(i)
ADJUSTMENT EXPLANATION
(j)
1
Electric Utility
2
3%
3
4%
4
7%
5
10%
4,826,274
223,478
4,602,796
(a)
20.5 years
8
TOTAL Electric (Enter Total of lines 2 thru 7)
4,826,274
223,478
4,602,796
9
Other (List separately and show 3%, 4%, 7%, 10% and TOTAL)
10
`
11
Mississippi ITC
4,236,025
2,073,959
6,309,984
47 OTHER TOTAL
4,236,025
2,073,959
6,309,984
48 GRAND TOTAL
9,062,299
2,073,959
223,478
10,912,780


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
FOOTNOTE DATA

(a) Concept: AccumulatedDeferredInvestmentTaxCreditsAveragePeriodOfAllocationToIncome
Average lives are based on estimated composite useful lives of the properties and are subject to reconsideration each year.

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
OTHER DEFERRED CREDITS (Account 253)
  1. Report below the particulars (details) called for concerning other deferred credits.
  2. For any deferred credit being amortized, show the period of amortization.
  3. Minor items (5% of the Balance End of Year for Account 253 or amounts less than $100,000, whichever is greater) may be grouped by classes.
DEBITS
Line No.
Description and Other Deferred Credits
(a)
Balance at Beginning of Year
(b)
Contra Account
(c)
Amount
(d)
Credits
(e)
Balance at End of Year
(f)
1
Long-Term Incentive Plan
283,504
135,984
158,524
306,044
2
Non-Qualified Pension funded status
3,670,778
210,576
58,071
3,518,273
3
Qualified Pension funded status
138,715,084
46,280,897
92,434,187
4
Choctaw purchase - escrow funds
15,700,000
15,700,000
5
Deferred Payroll Employer Tax
1,817,208
1,817,208
6
Employment Litigation
250,000
250,000
7
Deferred rebate
6,209
7,140
931
8
Other
9,430
9,430
47
TOTAL
160,192,783
64,151,805
476,025
96,517,003


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report


End of:
2021
/
Q4
ACCUMULATED DEFERRED INCOME TAXES - ACCELERATED AMORTIZATION PROPERTY (Account 281)
  1. Report the information called for below concerning the respondent’s accounting for deferred income taxes rating to amortizable property.
  2. For other (Specify),include deferrals relating to other income and deductions.
  3. Use footnotes as required.
CHANGES DURING YEAR ADJUSTMENTS
Debits Credits
Line No.
Account
(a)
Balance at Beginning of Year
(b)
Amounts Debited to Account 410.1
(c)
Amounts Credited to Account 411.1
(d)
Amounts Debited to Account 410.2
(e)
Amounts Credited to Account 411.2
(f)
Account Credited
(g)
Amount
(h)
Account Debited
(i)
Amount
(j)
Balance at End of Year
(k)
1
Accelerated Amortization (Account 281)
2
Electric
3
Defense Facilities
4
Pollution Control Facilities
5
Other
5.1
Other (provide details in footnote):
8
TOTAL Electric (Enter Total of lines 3 thru 7)
9
Gas
10
Defense Facilities
11
Pollution Control Facilities
12
Other
12.1
Other (provide details in footnote):
15
TOTAL Gas (Enter Total of lines 10 thru 14)
16
Other
16.1
Other
16.2
Other
17
TOTAL (Acct 281) (Total of 8, 15 and 16)
18
Classification of TOTAL
19
Federal Income Tax
20
State Income Tax
21
Local Income Tax


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
ACCUMULATED DEFERRED INCOME TAXES - OTHER PROPERTY (Account 282)
  1. Report the information called for below concerning the respondent’s accounting for deferred income taxes rating to property not subject to accelerated amortization.
  2. For other (Specify),include deferrals relating to other income and deductions.
  3. Use footnotes as required.
CHANGES DURING YEAR ADJUSTMENTS
Debits Credits
Line No.
Account
(a)
Balance at Beginning of Year
(b)
Amounts Debited to Account 410.1
(c)
Amounts Credited to Account 411.1
(d)
Amounts Debited to Account 410.2
(e)
Amounts Credited to Account 411.2
(f)
Account Credited
(g)
Amount
(h)
Account Debited
(i)
Amount
(j)
Balance at End of Year
(k)
1 Account 282
2
Electric
661,156,573
83,561,892
44,332,821
182.3/254
9,133,854
709,519,498
3
Gas
4
Other (Specify)
5
Total (Total of lines 2 thru 4)
661,156,573
83,561,892
44,332,821
9,133,854
709,519,498
6
7
8
9
TOTAL Account 282 (Total of Lines 5 thru 8)
661,156,573
83,561,892
44,332,821
9,133,854
709,519,498
10
Classification of TOTAL
11
Federal Income Tax
547,502,132
63,640,332
36,889,441
8,963,105
583,216,128
12
State Income Tax
113,654,441
19,921,560
7,443,380
170,749
126,303,370
13
Local Income Tax


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
ACCUMULATED DEFERRED INCOME TAXES - OTHER (Account 283)
  1. Report the information called for below concerning the respondent's accounting for deferred income taxes relating to amounts recorded in Account 283.
  2. For other (Specify),include deferrals relating to other income and deductions.
  3. Provide in the space below explanations for Page 276. Include amounts relating to insignificant items listed under Other.
  4. Use footnotes as required.
CHANGES DURING YEAR ADJUSTMENTS
Debits Credits
Line No.
Account
(a)
Balance at Beginning of Year
(b)
Amounts Debited to Account 410.1
(c)
Amounts Credited to Account 411.1
(d)
Amounts Debited to Account 410.2
(e)
Amounts Credited to Account 411.2
(f)
Account Credited
(g)
Amount
(h)
Account Debited
(i)
Amount
(j)
Balance at End of Year
(k)
1 Account 283
2
Electric
3
(a)
See Footnote Detail
538,416,707
55,710,401
20,609,413
16,942,436
6,266,969
562,842,228
9 TOTAL Electric (Total of lines 3 thru 8)
538,416,707
55,710,401
20,609,413
16,942,436
6,266,969
562,842,228
10
Gas
11
12
13
14
15
16
17 TOTAL Gas (Total of lines 11 thru 16)
18 TOTAL Other
19 TOTAL (Acct 283) (Enter Total of lines 9, 17 and 18)
538,416,707
55,710,401
20,609,413
16,942,436
6,266,969
562,842,228
20
Classification of TOTAL
21
Federal Income Tax
430,717,935
45,139,680
17,072,959
190
13,547,160
182.3/254
5,011,065
450,248,561
22
State Income Tax
107,698,772
10,570,721
3,536,454
190
3,395,276
182.3/254
1,255,904
112,593,667
23
Local Income Tax
NOTES


FOOTNOTE DATA

(a) Concept: DescriptionOfAccumulatedDeferredIncomeTaxOther
CHANGES DURING YEAR
BALANCE AT
BEGINNING
OF YEAR
AMOUNTS
DEBITED
TO ACCT.
410.1
AMOUNTS
CREDITED
TO ACCT.
411.1
AMOUNTS
DEBITED
TO ACCT.
410.2
AMOUNTS
CREDITED
TO ACCT.
411.2
Deferred Fuel ($1) $31,688,337  $1,279,721  $—  $— 
Reg Asset Covid 19 4,795,275  2,034,855  3,094,729  —  — 
Reg Asset-Securitization 15,731,877  15,733,576  8,635,749  —  — 
Minimum Pension Liability 58,488,318  —  —  —  — 
Bond Reacquisition Loss 3,372,428  14,248  352,813  —  — 
Section 475 Adj 453,390,322  34,815  862,078  —  — 
Distribution Maintenance (3,705) 3,861  156  —  — 
Capitalized Costs 2,071,648  11,276  279,227  —  — 
Misc Cap Costs 133,382  3,742  92,664  —  — 
Prepaid Expenses 437,143  1,048,678  875,263  —  — 
Decon & Decomm Fund —  5,137,013  5,137,013  —  — 
Income Tax Adjustment 20  —  —  —  — 
TOTAL $538,416,707  $55,710,401  $20,609,413  $—  $— 
ADJUSTMENTS
DEBITS CREDITS
ACCOUNT CREDITED AMOUNT ACCOUNT DEBITED AMOUNT BALANCE AT END OF YEAR
Deferred Fuel $—  $—  $30,408,615 
Reg Asset Covid 19 —  —  3,735,401 
Reg Asset-Securitization —  —  22,829,704 
Minimum Pension Liability 190  16,942,436  —  41,545,882 
Bond Reacquisition Loss —  —  3,033,863 
Section 475 Adj —  —  452,563,059 
Distribution Maintenance —  —  — 
Capitalized Costs —  —  1,803,697 
Misc Cap Costs —  —  44,460 
Prepaid Expenses —  —  610,558 
Decon & Decomm Fund —  —  — 
Income Tax Adjustment —  182.3/254 6,266,969  6,266,989 
TOTAL $16,942,436  $6,266,969  $562,842,228 

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
OTHER REGULATORY LIABILITIES (Account 254)
  1. Report below the particulars (details) called for concerning other regulatory liabilities, including rate order docket number, if applicable.
  2. Minor items (5% of the Balance in Account 254 at end of period, or amounts less than $100,000 which ever is less), may be grouped by classes.
  3. For Regulatory Liabilities being amortized, show period of amortization.
DEBITS
Line No.
Description and Purpose of Other Regulatory Liabilities
(a)
Balance at Beginning of Current Quarter/Year
(b)
Account Credited
(c)
Amount
(d)
Credits
(e)
Balance at End of Current Quarter/Year
(f)
1
Income Taxes
223,999,951
11,432,221
24,995,126
237,562,856
2
MISO Financial Transmission Rights Mark-to-Market
55,303
55,303
3
Grand Gulf Over-Recovery MPSC Docket No. 1984-UN-4620
1,041,956
14,072,097
15,114,053
4
Unit Power Cost Recovery Rider Over-Recovery MPSC Docket No. 2014-UN-132
10,018,905
2,845,755
7,173,150
5
MISO Rider Over-Recovery MPSC Docket No. 2014-UN-132
3,311,012
1,456,571
4,767,583
6
Power Management Rider Over-Recovery MPSC Docket No. 2014-UN-132
20,822,563
20,822,563
7
Choctaw Generating Station Over-Recovery - MPSC Docket No. 2018-UN-205
538,000
538,000
8
Grid Modernization Rider Over-Recovery MPSC Docket No. 2017-UN-198
863,116
572,358
1,435,474
9
Electric Deferred Fuel Over-Recovery
14,691,277
14,691,277
41 TOTAL
254,519,520
29,562,556
61,918,715
286,875,679


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
Electric Operating Revenues
  1. The following instructions generally apply to the annual version of these pages. Do not report quarterly data in columns (c), (e), (f), and (g). Unbilled revenues and MWH related to unbilled revenues need not be reported separately as required in the annual version of these pages.
  2. Report below operating revenues for each prescribed account, and manufactured gas revenues in total.
  3. Report number of customers, columns (f) and (g), on the basis of meters, in addition to the number of flat rate accounts; except that where separate meter readings are added for billing purposes, one customer should be counted for each group of meters added. The average number of customers means the average of twelve figures at the close of each month.
  4. If increases or decreases from previous period (columns (c),(e), and (g)), are not derived from previously reported figures, explain any inconsistencies in a footnote.
  5. Disclose amounts of $250,000 or greater in a footnote for accounts 451, 456, and 457.2.
  6. Commercial and industrial Sales, Account 442, may be classified according to the basis of classification (Small or Commercial, and Large or Industrial) regularly used by the respondent if such basis of classification is not generally greater than 1000 Kw of demand. (See Account 442 of the Uniform System of Accounts. Explain basis of classification in a footnote.)
  7. See page 108, Important Changes During Period, for important new territory added and important rate increase or decreases.
  8. For Lines 2,4,5,and 6, see Page 304 for amounts relating to unbilled revenue by accounts.
  9. Include unmetered sales. Provide details of such Sales in a footnote.
Line No.
Title of Account
(a)
Operating Revenues Year to Date Quarterly/Annual
(b)
Operating Revenues Previous year (no Quarterly)
(c)
MEGAWATT HOURS SOLD Year to Date Quarterly/Annual
(d)
MEGAWATT HOURS SOLD Amount Previous year (no Quarterly)
(e)
AVG.NO. CUSTOMERS PER MONTH Current Year (no Quarterly)
(f)
AVG.NO. CUSTOMERS PER MONTH Previous Year (no Quarterly)
(g)
1
SalesOfElectricityHeadingAbstract
Sales of Electricity
2
ResidentialSalesAbstract
(440) Residential Sales
578,258,495
523,378,532
5,568,055
5,378,310
383,468
379,705
3
CommercialAndIndustrialSalesAbstract
(442) Commercial and Industrial Sales
4
CommercialSalesAbstract
Small (or Comm.) (See Instr. 4)
(a)
439,949,537
(d)
395,875,123
4,468,879
4,283,143
66,343
65,003
5
IndustrialSalesAbstract
Large (or Ind.) (See Instr. 4)
150,697,534
145,100,256
2,297,663
2,342,917
4,006
3,620
6
PublicStreetAndHighwayLightingAbstract
(444) Public Street and Highway Lighting
15,770,896
14,895,516
77,286
79,387
429
432
7
OtherSalesToPublicAuthoritiesAbstract
(445) Other Sales to Public Authorities
30,476,742
27,059,979
333,052
318,116
4,741
4,737
8
SalesToRailroadsAndRailwaysAbstract
(446) Sales to Railroads and Railways
9
InterdepartmentalSalesAbstract
(448) Interdepartmental Sales
10
SalesToUltimateConsumersAbstract
TOTAL Sales to Ultimate Consumers
1,215,153,204
1,106,309,406
12,744,935
12,401,873
458,987
453,497
11
SalesForResaleAbstract
(447) Sales for Resale
124,631,972
77,530,332
4,363,569
4,316,175
12
SalesOfElectricityAbstract
TOTAL Sales of Electricity
1,339,785,176
1,183,839,738
17,108,504
16,718,048
458,987
453,497
13
ProvisionForRateRefundsAbstract
(Less) (449.1) Provision for Rate Refunds
14
RevenuesNetOfProvisionForRefundsAbstract
TOTAL Revenues Before Prov. for Refunds
1,339,785,176
1,183,839,738
17,108,504
16,718,048
458,987
453,497
15
OtherOperatingRevenuesAbstract
Other Operating Revenues
16
ForfeitedDiscounts
(450) Forfeited Discounts
5,785,312
7,021,236
17
MiscellaneousServiceRevenues
(451) Miscellaneous Service Revenues
(b)
2,551,400
(e)
3,702,761
18
SalesOfWaterAndWaterPower
(453) Sales of Water and Water Power
19
RentFromElectricProperty
(454) Rent from Electric Property
11,201,890
10,670,459
20
InterdepartmentalRents
(455) Interdepartmental Rents
21
OtherElectricRevenue
(456) Other Electric Revenues
(c)
3,389,694
(f)
6,268,521
22
RevenuesFromTransmissionOfElectricityOfOthers
(456.1) Revenues from Transmission of Electricity of Others
40,263,484
31,864,809
23
RegionalTransmissionServiceRevenues
(457.1) Regional Control Service Revenues
10,148,719
4,487,023
24
MiscellaneousRevenue
(457.2) Miscellaneous Revenues
25
OtherMiscellaneousOperatingRevenues
Other Miscellaneous Operating Revenues
26
OtherOperatingRevenues
TOTAL Other Operating Revenues
66,561,111
64,014,809
27
ElectricOperatingRevenues
TOTAL Electric Operating Revenues
1,406,346,287
1,247,854,547
Line12, column (b) includes $
of unbilled revenues.
Line12, column (d) includes
MWH relating to unbilled revenues


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
FOOTNOTE DATA

(a) Concept: SmallOrCommercialSalesElectricOperatingRevenue
Basis of classification of Commercial and Industrial Sales Account 442: (a) Industrial - Standard Classification Manual; (b) Commercial - all other business or professional activities of a non-manufacturing nature.
(b) Concept: MiscellaneousServiceRevenues
Revenues from connections and reconnections.
(c) Concept: OtherElectricRevenue
MISO Mkt Sch 11 Wholesale Dist $1,018,414 
Ouachita Upgrades 970,860 
Grid Modernization 2,866 
MS Department of Revenue - Vendor discount 1,200 
Third Party Sales of Inventory (3,322)
Choctaw Interim Recovery Rider (1,899,050)
Unbilled Revenue - Includes (102,252) MWH (3,480,662)
Total ($3,389,694)
(d) Concept: SmallOrCommercialSalesElectricOperatingRevenue
Basis of classification of Commercial and Industrial Sales Account 442: (a) Industrial - Standard Classification Manual; (b) Commercial - all other business or professional activities of a non-manufacturing nature.
(e) Concept: MiscellaneousServiceRevenues
Revenues from connections and reconnections.
(f) Concept: OtherElectricRevenue
MISO Mkt Sch 11 Wholesale Dist $1,092,062 
Ouachita Upgrades 970,860 
MS Department of Revenue - Vendor discount 1,200 
Third Party Sales of Inventory 2,628 
Choctaw Interim Recovery Rider (7,886,741)
Unbilled Revenue - Includes 58,401 MWH 12,088,332 
Other $180 
Total $6,268,521 

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
REGIONAL TRANSMISSION SERVICE REVENUES (Account 457.1)
  1. The respondent shall report below the revenue collected for each service (i.e., control area administration, market administration, etc.) performed pursuant to a Commission approved tariff. All amounts separately billed must be detailed below.
Line No.
Description of Service
(a)
Balance at End of Quarter 1
(b)
Balance at End of Quarter 2
(c)
Balance at End of Quarter 3
(d)
Balance at End of Year
(e)
1
MISO Sch 1 Sched/Sys Ctrl/Disp
171,080
313,737
483,748
627,022
2
MISO Sch 2 Reactive
2,150,186
4,439,804
7,431,548
9,521,697
46
TOTAL
2,321,266
4,753,541
7,915,296
10,148,719


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
SALES OF ELECTRICITY BY RATE SCHEDULES
  1. Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310.
  2. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading.
  3. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers.
  4. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly).
  5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto.
  6. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.
Number and Title of Rate Schedule
(a)
MWh Sold
(b)
Revenue
(c)
Average Number of Customers
(d)
KWh of Sales Per Customer
(e)
Revenue Per KWh Sold
(f)
1
RS-38C Residential Service
3,604,198
380,038,908
260,890
13,815
0.1054
2
RS-38W Residential Water Heating Service
1,929,639
188,735,532
121,572
15,872
0.0978
3
PAL-17 Private Area Lighting
30,653
8,002,713
842
36,405
0.2611
4
UFL-16 Urban Flood Lighting
6
879
1
6,000
0.1465
5
RFL-16 Rural Flood Lighting
2
317
1
2,000
0.1585
6
DSL-16 Directional Security  Lighting
1,657
444,139
65
25,492
0.2680
7
LED-2 LED Street and Area  Lighting
1,900
1,052,188
96
19,792
0.5538
8
GS-298 General Lighting and Power
16,181
9
IPS-26 Irrigation Pumping Power
1
41 TOTAL Billed Residential Sales
5,568,055
(a)
578,258,495
383,468
14,520
0.1039
42 TOTAL Unbilled Rev. (See Instr. 6)
43 TOTAL
5,568,055
578,258,495
383,468
14,520
0.1039


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
FOOTNOTE DATA

(a) Concept: ResidentialSalesBilled
Residential
Includes fuel adjustment revenues of:
RS-38C Residential Service ($71,392,510)
RS-38W Residential Water Heating Service (38,134,405)
PAL-17 Private Area Lighting (608,383)
UFL-16 Urban Flood Lighting (126)
RFL-16 Rural Flood Lighting (36)
DSL-16 Directional Security Lighting (32,847)
GS-298 General Lighting and Power — 
HL-21 Public Highway & Park Lighting — 
LED-2 LED Street and Area Lighting (37,742)
TOTAL RESIDENTIAL FUEL ADJUSTMENT REVENUES ($110,206,049)

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
SALES OF ELECTRICITY BY RATE SCHEDULES
  1. Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310.
  2. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading.
  3. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers.
  4. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly).
  5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto.
  6. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.
Number and Title of Rate Schedule
(a)
MWh Sold
(b)
Revenue
(c)
Average Number of Customers
(d)
KWh of Sales Per Customer
(e)
Revenue Per KWh Sold
(f)
1
GS-298 General Lighting and Power
2,380,582
277,240,712
63,894
37,258
0.1165
2
HLF-7 High Load Factor
1,116,925
80,447,803
310
3,602,984
0.0720
3
PAL-17 Private Area Lighting
15,799
4,402,504
874
18,077
0.2787
4
UFL-16 Urban Flood Lighting
254
36,783
21
12,095
0.1448
5
RFL-16 Rural Flood Lighting
7
1,303
0.1861
6
DSL-16 Directional Security  Lighting
34,988
6,910,746
647
54,077
0.1975
7
LED-2 LED Street and Area  Lighting
13,802
4,387,303
180
76,678
0.3179
8
B-34 Intermediate General Service
330,986
30,017,145
277
1,194,895
0.0907
9
SL-37 Municipal Street Lighting
26,597
4
10
TF-23 Traffic Control Signals
11
1,059
1
11,000
0.0963
11
FAYETTE
387
14,135
1
387,000
0.0365
12
IPS-26 Irrigation Pumping Power
2
794
2
1,000
0.3970
13
GS-298 MS Gen. Lghtg & Pwr Muni. Service
22
2,858
3
7,333
0.1299
14
QF-18
140
1
15
Miscellaneous
8,160
83
16
ALGS-10 Alternate Large General Service
406,577
24,164,310
6
67,762,833
0.0594
17
MP-22 Municipal Pumping Power Service
12
3,174
0.2645
18
GLP-17 Gen. Lghtg. & Pwr Redist. & Res.
1,366
141,853
1
1,366,000
0.1038
19
C-29 Large General Service
166,867
12,112,855
14
11,919,071
0.0726
20
SWH-20 Gen. Space and Water Heating Serv.
363
36,967
18
20,167
0.1018
21
RS-38C Residential Service
55
6,237
6
9,167
0.1134
22
RS-38W Residential Water Heating Service
16
1,427
0.0892
41 TOTAL Billed Small or Commercial
4,468,879
(a)
439,949,537
66,343
67,360
0.0984
42 TOTAL Unbilled Rev. Small or Commercial (See Instr. 6)
43 TOTAL Small or Commercial
4,468,879
(b)
439,949,537
66,343
67,360
0.0984


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
FOOTNOTE DATA

(a) Concept: SmallOrCommercialSalesElectricOperatingRevenueBilled
Commercial
Includes Fuel Adjustment Revenues of:
GS-298 General Lighting and Power ($47,183,947)
B-34 Intermediate General Service (6,557,849)
C-29 Large General Service (3,308,914)
ALGS-10 Alternate Large General Service (8,062,268)
HLF-7 High Load Factor General Service (22,138,229)
FAYETTE — 
GLP-17 Gen. Lghtg. & Pwr for Redist. & Res. (27,086)
DSL-16 Directional Security Lighting (692,879)
SWH-20 Gen. Space and Water Heating Serv. (7,192)
PAL-17 Private Area Lighting ($313,047)
UFL-16 Urban Flood Lighting (5,051)
RFL-16 Rural Flood Lighting (143)
RS-38C Residential Service 462 
RS-38W Residential Water Heating Service 122 
TF-23 Traffic Control Signal (219)
MP-22 Municipal Pumping Power (242)
IPS-26 Irrigation Pumping Power (64)
HL-21 Public Highway & Park Lighting — 
SL-37 Municipal Street Lighting — 
LED-2 LED Street and Area Lighting (273,765)
SE-29 State Institutions Service — 
GS-298 MS Gen L&P Muni Service (437)
GS-298X Gen L&P TOU — 
TOTAL COMMERCIAL FUEL ADJUSTMENT REVENUES ($88,570,748)
(b) Concept: SmallOrCommercialSalesElectricOperatingRevenue
Basis of classification of Commercial and Industrial Sales Account 442: (a) Industrial - Standard Classification Manual; (b) Commercial - all other business or professional activities of a non-manufacturing nature.

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
SALES OF ELECTRICITY BY RATE SCHEDULES
  1. Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310.
  2. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading.
  3. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers.
  4. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly).
  5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto.
  6. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.
Number and Title of Rate Schedule
(a)
MWh Sold
(b)
Revenue
(c)
Average Number of Customers
(d)
KWh of Sales Per Customer
(e)
Revenue Per KWh Sold
(f)
1
GS-298 General Lighting and Power
137,847
16,306,828
2,111
65,299
0.1183
2
HLF-7 High Load Factor
571,560
39,903,206
78
7,327,692
0.0698
3
PAL-17 Private Area Lighting
537
136,154
21
25,571
0.2535
4
UFL-16 Urban Flood Lighting
8
1,322
1
8,000
0.1653
5
RFL-16 Rural Flood Lighting
2
317
0.1585
6
DSL-16 Directional Security  Lighting
2,288
424,079
20
114,400
0.1853
7
LED-2 LED Street and Area  Lighting
478
132,743
3
159,333
0.2777
8
B-34 Intermediate General Service
160,962
15,966,544
90
1,788,467
0.0992
9
C-29 Large General Service
215,983
17,089,690
29
7,447,690
0.0791
10
IPS-26 Irrigation Pumping Power
20,202
3,764,213
1,567
12,892
0.1863
11
IP-33 Ice Manufacturing Plant Power
292
28,616
1
292,000
0.0980
12
ALGS-10 / Other
687,320
42,409,508
16
42,957,500
0.0617
13
Contract Rates
497,591
14,199,273
4
124,397,750
0.0285
14
GS-298X
2,599
335,490
63
41,254
0.1291
15
GS-298 MS Gen. Lghtg & Pwr Muni. Service
6
449
1
6,000
0.0748
16
RS-38C Residential Service
1
41 TOTAL Billed Large (or Ind.) Sales
2,297,663
(a)
150,697,534
4,006
573,555
0.0656
42 TOTAL Unbilled Rev. Large (or Ind.) (See Instr. 6)
43 TOTAL Large (or Ind.)
2,297,663
150,697,534
4,006
573,555
0.0656


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
FOOTNOTE DATA

(a) Concept: LargeOrIndustrialSalesElectricOperatingRevenueBilled
Industrial
Includes Fuel Adjustment Revenues of:
GS-298 General Lighting and Power ($2,713,030)
B-34 Intermediate General Service (3,175,945)
C-29 Large General Service (4,280,627)
ALGS-10 / Other (14,505,318)
HLF-7 High Load Factor General Service (11,332,245)
DSL-16 Directional Security Lighting (45,310)
IPS-26 Irrigation Pumping Power (409,918)
IP-33 Ice Manufacturing Plant Power (5,734)
PAL-17 Private Area Lighting Service (10,639)
UFL-16 Urban Flood Lighting Service ($155)
RFL-16 Rural Flood Lighting Service (36)
SL-37 Municipal Street Lighting — 
LED-2 LED Street and Area Lighting (9,478)
GS-298 MS Gen L&P Muni Service 155 
GS-298X Gen L&P TOU (51,578)
RS-38W Residential Water Heating Service — 
TOTAL INDUSTRIAL FUEL ADJUSTMENT REVENUES ($36,539,858)

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
SALES OF ELECTRICITY BY RATE SCHEDULES
  1. Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310.
  2. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading.
  3. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers.
  4. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly).
  5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto.
  6. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.
Number and Title of Rate Schedule
(a)
MWh Sold
(b)
Revenue
(c)
Average Number of Customers
(d)
KWh of Sales Per Customer
(e)
Revenue Per KWh Sold
(f)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41 TOTAL Billed Commercial and Industrial Sales
42 TOTAL Unbilled Rev. (See Instr. 6)
43 TOTAL


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
SALES OF ELECTRICITY BY RATE SCHEDULES
  1. Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310.
  2. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading.
  3. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers.
  4. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly).
  5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto.
  6. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.
Number and Title of Rate Schedule
(a)
MWh Sold
(b)
Revenue
(c)
Average Number of Customers
(d)
KWh of Sales Per Customer
(e)
Revenue Per KWh Sold
(f)
1
SL-37 Municipal Street Lighting
60,668
14,250,289
137
442,832
0.2349
2
HL-21 Public Highway & Park Lighting
12,521
1,018,499
89
140,685
0.0813
3
TF-23 Traffic Control Signals
4,021
466,746
194
20,727
0.1161
4
LED-2 LED Street and Area  Lighting
76
35,362
9
8,444
0.4653
41 TOTAL Billed Public Street and Highway Lighting
77,286
(a)
15,770,896
429
180,154
0.2041
42 TOTAL Unbilled Rev. (See Instr. 6)
43 TOTAL
77,286
15,770,896
429
180,154
0.2041


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
FOOTNOTE DATA

(a) Concept: PublicStreetAndHighwayLightingBilled
Public Street and Highway Lighting
Includes Fuel Adjustment Revenues of:
TF-23 Traffic Control Signals ($79,601)
HL-21 Public Highway & Park Lighting (248,064)
SL-37 Municipal Street Lighting (1,200,677)
DSL-16 Directional Security Lighting — 
PAL-17 Private Area Lighting Service — 
LED-2 LED Street and Area Lighting (1,508)
TOTAL PUBLIC STREET AND HIGHWAY LIGHTING FUEL ADJUSTMENT REVENUES ($1,529,850)

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
SALES OF ELECTRICITY BY RATE SCHEDULES
  1. Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310.
  2. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading.
  3. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers.
  4. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly).
  5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto.
  6. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.
Number and Title of Rate Schedule
(a)
MWh Sold
(b)
Revenue
(c)
Average Number of Customers
(d)
KWh of Sales Per Customer
(e)
Revenue Per KWh Sold
(f)
1
GS-298 MS Gen. Lghtg & Pwr Muni. Service
176,500
16,374,576
2,690
65,613
0.0928
2
MP-22 Municipal Pumping Power Service
84,206
8,489,829
1,948
43,227
0.1008
3
SE-29 State Institutions
69,011
4,913,299
8
8,626,375
0.0712
4
GS-298 General Lighting and Power
180
21,650
8
22,500
0.1203
5
SL-37 Municipal Street Lighting
537
6
PAL-17 Private Area Lighting
489
125,637
19
25,737
0.2569
7
DSL-16 Directional Security  Lighting
2,333
447,621
61
38,246
0.1919
8
LED-2 LED Street and Area  Lighting
328
103,008
7
46,857
0.3140
9
UFL-16 Urban Flood Lighting
5
585
0.1170
41 TOTAL Billed Other Sales to Public Authorities
333,052
(a)
30,476,742
4,741
70,249
0.0915
42 TOTAL Unbilled Rev. (See Instr. 6)
43 TOTAL
333,052
30,476,742
4,741
70,249
0.0915


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
FOOTNOTE DATA

(a) Concept: OtherSalesToPublicAuthoritiesBilled
Other Sales to Public Authorities
Includes Fuel Adjustment Revenues of:
GS-298 MS Gen. Lghtg & Pwr Muni.Service ($3,496,573)
MP-22 Municipal Pumping Power Service (1,664,231)
SE-29 State Institutions (1,369,170)
DSL-16 Directional Security Lighting (46,179)
PAL-17 Private Area Lighting (9,676)
UFL-16 Urban Flood Lighting (90)
HL-21 Public Highway & Park Ltg — 
GS-298 General Lighting and Power (3,491)
RS-38W Residential Water Heating Service — 
LED-2 LED Street and Area Lighting (6,488)
B-34 Intermediate General Service — 
TOTAL OTHER SALES TO PUBLIC AUTH FUEL ADJ REV ($6,595,898)

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
SALES OF ELECTRICITY BY RATE SCHEDULES
  1. Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310.
  2. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading.
  3. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers.
  4. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly).
  5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto.
  6. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.
Number and Title of Rate Schedule
(a)
MWh Sold
(b)
Revenue
(c)
Average Number of Customers
(d)
KWh of Sales Per Customer
(e)
Revenue Per KWh Sold
(f)
41 TOTAL Billed - All Accounts
12,744,935
1,215,153,204
458,987
27,768
0.0953
42 TOTAL Unbilled Rev. (See Instr. 6) - All Accounts
43 TOTAL - All Accounts
12,744,935
1,215,153,204
458,987
27,768
0.0953


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
SALES FOR RESALE (Account 447)
  1. Report all sales for resale (i.e., sales to purchasers other than ultimate consumers) transacted on a settlement basis other than power exchanges during the year. Do not report exchanges of electricity ( i.e., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges on this schedule. Power exchanges must be reported on the Purchased Power schedule (Page 326).
  2. Enter the name of the purchaser in column (a). Do note abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the purchaser.
  3. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:

    RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (i.e., the supplier includes projected load for this service in its system resource planning). In addition, the reliability of requirements service must be the same as, or second only to, the supplier's service to its own ultimate consumers.

    LF - for tong-term service. "Long-term" means five years or Longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e.g., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for Long-term firm service which meets the definition of RQ service. For all transactions identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or setter can unilaterally get out of the contract.

    IF - for intermediate-term firm service. The same as LF service except that "intermediate-term" means longer than one year but Less than five years.

    SF - for short-term firm service. Use this category for all firm services where the duration of each period of commitment for service is one year or less.

    LU - for Long-term service from a designated generating unit. "Long-term" means five years or Longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of designated unit.

    IU - for intermediate-term service from a designated generating unit. The same as LU service except that "intermediate-term" means Longer than one year but Less than five years.

    OS - for other service. use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote.

    AD - for Out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment.

  4. Group requirements RQ sales together and report them starting at line number one. After listing all RQ sales, enter "Subtotal - RQ" in column (a). The remaining sales may then be listed in any order. Enter "Subtotal-Non-RQ" in column (a) after this Listing. Enter "Total'' in column (a) as the Last Line of the schedule. Report subtotals and total for columns (g) through (k).
  5. In Column (c), identify the FERC Rate Schedule or Tariff Number. On separate Lines, List all FERC rate schedules or tariffs under which service, as identified in column (b), is provided.
  6. For requirements RQ sales and any type of-service involving demand charges imposed on a monthly (or Longer) basis, enter the average monthly billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (f). For all other types of service, enter NA in columns (d), (e) and (f). Monthly NCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (f) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain.
  7. Report in column (g) the megawatt hours shown on bills rendered to the purchaser.
  8. Report demand charges in column (h), energy charges in column (i), and the total of any other types of charges, including out-of-period adjustments, in column (j). Explain in a footnote all components of the amount shown in column (j). Report in column (k) the total charge shown on bills rendered to the purchaser.
  9. The data in column (g) through (k) must be subtotaled based on the RQ/Non-RQ grouping (see instruction 4), and then totaled on the Last -line of the schedule. The "Subtotal - RQ" amount in column (g) must be reported as Requirements Sales For Resale on Page 401, line 23. The "Subtotal - Non-RQ" amount in column (g) must be reported as Non-Requirements Sales For Resale on Page 401,line 24.
  10. Footnote entries as required and provide explanations following all required data.
ACTUAL DEMAND (MW) REVENUE
Line No.
Name of Company or Public Authority (Footnote Affiliations)
(a)
Statistical Classification
(b)
FERC Rate Schedule or Tariff Number
(c)
Average Monthly Billing Demand (MW)
(d)
Average Monthly NCP Demand
(e)
Average Monthly CP Demand
(f)
Megawatt Hours Sold
(g)
Demand Charges ($)
(h)
Energy Charges ($)
(i)
Other Charges ($)
(j)
Total ($) (h+i+j)
(k)
1
Midcontinent ISO, Inc.
4,363,569
31,532
122,203,045
(a)
1,972,607
124,207,184
2
Entergy System Power Pool
(b)
424,788
424,788
15
Subtotal - RQ
16
Subtotal-Non-RQ
4,363,569
31,532
122,203,045
2,397,395
124,631,972
17 Total
4,363,569
31,532
122,203,045
2,397,395
124,631,972


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
FOOTNOTE DATA

(a) Concept: OtherChargesRevenueSalesForResale
MISO Residual Load $743,800 
MISO Uplift 1,228,807 
Total $1,972,607 
(b) Concept: OtherChargesRevenueSalesForResale
Settlement of Rough Production Cost Equalization per FERC Docket Nos. EL10-65-008 and EL10-65-009.

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
ELECTRIC OPERATION AND MAINTENANCE EXPENSES

If the amount for previous year is not derived from previously reported figures, explain in footnote.

Line No.
Account
(a)
Amount for Current Year
(b)
Amount for Previous Year (c)
(c)
1
PowerProductionExpensesAbstract
1. POWER PRODUCTION EXPENSES
2
SteamPowerGenerationAbstract
A. Steam Power Generation
3
SteamPowerGenerationOperationAbstract
Operation
4
OperationSupervisionAndEngineeringSteamPowerGeneration
(500) Operation Supervision and Engineering
4,544,995
4,931,179
5
FuelSteamPowerGeneration
(501) Fuel
(a)
318,054,549
(b)
242,747,661
6
SteamExpensesSteamPowerGeneration
(502) Steam Expenses
2,278,994
2,286,355
7
SteamFromOtherSources
(503) Steam from Other Sources
8
SteamTransferredCredit
(Less) (504) Steam Transferred-Cr.
9
ElectricExpensesSteamPowerGeneration
(505) Electric Expenses
603,100
643,878
10
MiscellaneousSteamPowerExpenses
(506) Miscellaneous Steam Power Expenses
8,181,881
7,842,840
11
RentsSteamPowerGeneration
(507) Rents
21,732
448,453
12
Allowances
(509) Allowances
26,384
50,040
13
SteamPowerGenerationOperationsExpense
TOTAL Operation (Enter Total of Lines 4 thru 12)
333,711,635
258,950,406
14
SteamPowerGenerationMaintenanceAbstract
Maintenance
15
MaintenanceSupervisionAndEngineeringSteamPowerGeneration
(510) Maintenance Supervision and Engineering
500,249
557,530
16
MaintenanceOfStructuresSteamPowerGeneration
(511) Maintenance of Structures
745,604
981,398
17
MaintenanceOfBoilerPlantSteamPowerGeneration
(512) Maintenance of Boiler Plant
7,965,946
7,932,147
18
MaintenanceOfElectricPlantSteamPowerGeneration
(513) Maintenance of Electric Plant
3,517,853
2,987,396
19
MaintenanceOfMiscellaneousSteamPlant
(514) Maintenance of Miscellaneous Steam Plant
19,129,509
17,193,594
20
SteamPowerGenerationMaintenanceExpense
TOTAL Maintenance (Enter Total of Lines 15 thru 19)
31,859,161
29,652,065
21
PowerProductionExpensesSteamPower
TOTAL Power Production Expenses-Steam Power (Enter Total of Lines 13 & 20)
365,570,796
288,602,471
22
NuclearPowerGenerationAbstract
B. Nuclear Power Generation
23
NuclearPowerGenerationOperationAbstract
Operation
24
OperationSupervisionAndEngineeringNuclearPowerGeneration
(517) Operation Supervision and Engineering
25
NuclearFuelExpense
(518) Fuel
26
CoolantsAndWater
(519) Coolants and Water
27
SteamExpensesNuclearPowerGeneration
(520) Steam Expenses
28
SteamFromOtherSourcesNuclearPowerGeneration
(521) Steam from Other Sources
29
SteamTransferredCreditNuclearPowerGeneration
(Less) (522) Steam Transferred-Cr.
30
ElectricExpensesNuclearPowerGeneration
(523) Electric Expenses
31
MiscellaneousNuclearPowerExpenses
(524) Miscellaneous Nuclear Power Expenses
32
RentsNuclearPowerGeneration
(525) Rents
33
NuclearPowerGenerationOperationsExpense
TOTAL Operation (Enter Total of lines 24 thru 32)
34
NuclearPowerGenerationMaintenanceAbstract
Maintenance
35
MaintenanceSupervisionAndEngineeringNuclearPowerGeneration
(528) Maintenance Supervision and Engineering
36
MaintenanceOfStructuresNuclearPowerGeneration
(529) Maintenance of Structures
37
MaintenanceOfReactorPlantEquipmentNuclearPowerGeneration
(530) Maintenance of Reactor Plant Equipment
38
MaintenanceOfElectricPlantNuclearPowerGeneration
(531) Maintenance of Electric Plant
39
MaintenanceOfMiscellaneousNuclearPlant
(532) Maintenance of Miscellaneous Nuclear Plant
40
NuclearPowerGenerationMaintenanceExpense
TOTAL Maintenance (Enter Total of lines 35 thru 39)
41
PowerProductionExpensesNuclearPower
TOTAL Power Production Expenses-Nuclear. Power (Enter Total of lines 33 & 40)
42
HydraulicPowerGenerationAbstract
C. Hydraulic Power Generation
43
HydraulicPowerGenerationOperationAbstract
Operation
44
OperationSupervisionAndEngineeringHydraulicPowerGeneration
(535) Operation Supervision and Engineering
45
WaterForPower
(536) Water for Power
46
HydraulicExpenses
(537) Hydraulic Expenses
47
ElectricExpensesHydraulicPowerGeneration
(538) Electric Expenses
48
MiscellaneousHydraulicPowerGenerationExpenses
(539) Miscellaneous Hydraulic Power Generation Expenses
49
RentsHydraulicPowerGeneration
(540) Rents
50
HydraulicPowerGenerationOperationsExpense
TOTAL Operation (Enter Total of Lines 44 thru 49)
51
HydraulicPowerGenerationContinuedAbstract
C. Hydraulic Power Generation (Continued)
52
HydraulicPowerGenerationMaintenanceAbstract
Maintenance
53
MaintenanceSupervisionAndEngineeringHydraulicPowerGeneration
(541) Mainentance Supervision and Engineering
54
MaintenanceOfStructuresHydraulicPowerGeneration
(542) Maintenance of Structures
55
MaintenanceOfReservoirsDamsAndWaterways
(543) Maintenance of Reservoirs, Dams, and Waterways
56
MaintenanceOfElectricPlantHydraulicPowerGeneration
(544) Maintenance of Electric Plant
57
MaintenanceOfMiscellaneousHydraulicPlant
(545) Maintenance of Miscellaneous Hydraulic Plant
58
HydraulicPowerGenerationMaintenanceExpense
TOTAL Maintenance (Enter Total of lines 53 thru 57)
59
PowerProductionExpensesHydraulicPower
TOTAL Power Production Expenses-Hydraulic Power (Total of Lines 50 & 58)
60
OtherPowerGenerationAbstract
D. Other Power Generation
61
OtherPowerGenerationOperationAbstract
Operation
62
OperationSupervisionAndEngineeringOtherPowerGeneration
(546) Operation Supervision and Engineering
994,428
957,089
63
Fuel
(547) Fuel
64
GenerationExpenses
(548) Generation Expenses
809,873
794,577
64.1
OperationOfEnergyStorageEquipment
(548.1) Operation of Energy Storage Equipment
65
MiscellaneousOtherPowerGenerationExpenses
(549) Miscellaneous Other Power Generation Expenses
8,944,873
8,973,730
66
RentsOtherPowerGeneration
(550) Rents
92,131
87,883
67
OtherPowerGenerationOperationsExpense
TOTAL Operation (Enter Total of Lines 62 thru 67)
10,841,305
10,813,279
68
OtherPowerGenerationMaintenanceAbstract
Maintenance
69
MaintenanceSupervisionAndEngineeringOtherPowerGeneration
(551) Maintenance Supervision and Engineering
37,459
15,959
70
MaintenanceOfStructures
(552) Maintenance of Structures
341,996
336,456
71
MaintenanceOfGeneratingAndElectricPlant
(553) Maintenance of Generating and Electric Plant
5,790,155
8,003,441
71.1
MaintenanceOfEnergyStorageEquipmentOtherPowerGeneration
(553.1) Maintenance of Energy Storage Equipment
72
MaintenanceOfMiscellaneousOtherPowerGenerationPlant
(554) Maintenance of Miscellaneous Other Power Generation Plant
526,849
351,149
73
OtherPowerGenerationMaintenanceExpense
TOTAL Maintenance (Enter Total of Lines 69 thru 72)
6,696,459
8,707,005
74
PowerProductionExpensesOtherPower
TOTAL Power Production Expenses-Other Power (Enter Total of Lines 67 & 73)
17,537,764
19,520,284
75
OtherPowerSuplyExpensesAbstract
E. Other Power Supply Expenses
76
PurchasedPower
(555) Purchased Power
297,967,897
240,457,288
76.1
PowerPurchasedForStorageOperations
(555.1) Power Purchased for Storage Operations
0
77
SystemControlAndLoadDispatchingElectric
(556) System Control and Load Dispatching
676,994
734,298
78
OtherExpensesOtherPowerSupplyExpenses
(557) Other Expenses
136,362,952
55,543,803
79
OtherPowerSupplyExpense
TOTAL Other Power Supply Exp (Enter Total of Lines 76 thru 78)
162,281,939
185,647,783
80
PowerProductionExpenses
TOTAL Power Production Expenses (Total of Lines 21, 41, 59, 74 & 79)
545,390,499
493,770,538
81
TransmissionExpensesAbstract
2. TRANSMISSION EXPENSES
82
TransmissionExpensesOperationAbstract
Operation
83
OperationSupervisionAndEngineeringElectricTransmissionExpenses
(560) Operation Supervision and Engineering
2,694,179
2,462,080
85
LoadDispatchReliability
(561.1) Load Dispatch-Reliability
86
LoadDispatchMonitorAndOperateTransmissionSystem
(561.2) Load Dispatch-Monitor and Operate Transmission System
2,152,248
2,033,776
87
LoadDispatchTransmissionServiceAndScheduling
(561.3) Load Dispatch-Transmission Service and Scheduling
45,110
63,278
88
SchedulingSystemControlAndDispatchServices
(561.4) Scheduling, System Control and Dispatch Services
4,182,192
3,821,714
89
ReliabilityPlanningAndStandardsDevelopment
(561.5) Reliability, Planning and Standards Development
333,098
413,688
90
TransmissionServiceStudies
(561.6) Transmission Service Studies
2,910
91
GenerationInterconnectionStudies
(561.7) Generation Interconnection Studies
92
ReliabilityPlanningAndStandardsDevelopmentServices
(561.8) Reliability, Planning and Standards Development Services
552,456
495,548
93
StationExpensesTransmissionExpense
(562) Station Expenses
209,844
275,567
93.1
OperationOfEnergyStorageEquipmentTransmissionExpense
(562.1) Operation of Energy Storage Equipment
94
OverheadLineExpense
(563) Overhead Lines Expenses
812,538
879,265
95
UndergroundLineExpensesTransmissionExpense
(564) Underground Lines Expenses
96
TransmissionOfElectricityByOthers
(565) Transmission of Electricity by Others
7,731,993
3,359,878
97
MiscellaneousTransmissionExpenses
(566) Miscellaneous Transmission Expenses
907,443
1,118,660
98
RentsTransmissionElectricExpense
(567) Rents
686,521
593,623
99
TransmissionOperationExpense
TOTAL Operation (Enter Total of Lines 83 thru 98)
20,310,532
15,517,077
100
TransmissionMaintenanceAbstract
Maintenance
101
MaintenanceSupervisionAndEngineeringElectricTransmissionExpenses
(568) Maintenance Supervision and Engineering
2,473,668
2,898,678
102
MaintenanceOfStructuresTransmissionExpense
(569) Maintenance of Structures
235,382
163,955
103
MaintenanceOfComputerHardwareTransmission
(569.1) Maintenance of Computer Hardware
2,433
104
MaintenanceOfComputerSoftwareTransmission
(569.2) Maintenance of Computer Software
54,133
19,230
105
MaintenanceOfCommunicationEquipmentElectricTransmission
(569.3) Maintenance of Communication Equipment
106
MaintenanceOfMiscellaneousRegionalTransmissionPlant
(569.4) Maintenance of Miscellaneous Regional Transmission Plant
107
MaintenanceOfStationEquipmentTransmission
(570) Maintenance of Station Equipment
1,921,776
1,691,155
107.1
MaintenanceOfEnergyStorageEquipmentTransmission
(570.1) Maintenance of Energy Storage Equipment
108
MaintenanceOfOverheadLinesTransmission
(571) Maintenance of Overhead Lines
3,647,894
4,084,725
109
MaintenanceOfUndergroundLinesTransmission
(572) Maintenance of Underground Lines
110
MaintenanceOfMiscellaneousTransmissionPlant
(573) Maintenance of Miscellaneous Transmission Plant
64,442
34,490
111
TransmissionMaintenanceExpenseElectric
TOTAL Maintenance (Total of Lines 101 thru 110)
8,399,728
8,892,233
112
TransmissionExpenses
TOTAL Transmission Expenses (Total of Lines 99 and 111)
28,710,260
24,409,310
113
RegionalMarketExpensesAbstract
3. REGIONAL MARKET EXPENSES
114
RegionalMarketExpensesOperationAbstract
Operation
115
OperationSupervision
(575.1) Operation Supervision
116
DayAheadAndRealTimeMarketAdministration
(575.2) Day-Ahead and Real-Time Market Facilitation
117
TransmissionRightsMarketAdministration
(575.3) Transmission Rights Market Facilitation
118
CapacityMarketAdministration
(575.4) Capacity Market Facilitation
119
AncillaryServicesMarketAdministration
(575.5) Ancillary Services Market Facilitation
120
MarketMonitoringAndCompliance
(575.6) Market Monitoring and Compliance
121
MarketFacilitationMonitoringAndComplianceServices
(575.7) Market Facilitation, Monitoring and Compliance Services
2,673,202
2,868,273
122
RentsRegionalMarketExpenses
(575.8) Rents
123
RegionalMarketOperationExpense
Total Operation (Lines 115 thru 122)
2,673,202
2,868,273
124
RegionalMarketExpensesMaintenanceAbstract
Maintenance
125
MaintenanceOfStructuresAndImprovementsRegionalMarketExpenses
(576.1) Maintenance of Structures and Improvements
126
MaintenanceOfComputerHardware
(576.2) Maintenance of Computer Hardware
127
MaintenanceOfComputerSoftware
(576.3) Maintenance of Computer Software
128
MaintenanceOfCommunicationEquipmentRegionalMarketExpenses
(576.4) Maintenance of Communication Equipment
129
MaintenanceOfMiscellaneousMarketOperationPlant
(576.5) Maintenance of Miscellaneous Market Operation Plant
130
RegionalMarketMaintenanceExpense
Total Maintenance (Lines 125 thru 129)
131
RegionalMarketExpenses
TOTAL Regional Transmission and Market Operation Expenses (Enter Total of Lines 123 and 130)
2,673,202
2,868,273
132
DistributionExpensesAbstract
4. DISTRIBUTION EXPENSES
133
DistributionExpensesOperationAbstract
Operation
134
OperationSupervisionAndEngineeringDistributionExpense
(580) Operation Supervision and Engineering
11,477,640
9,584,852
135
LoadDispatching
(581) Load Dispatching
148,665
139,380
136
StationExpensesDistribution
(582) Station Expenses
185,661
215,025
137
OverheadLineExpenses
(583) Overhead Line Expenses
1,037,680
1,250,430
138
UndergroundLineExpenses
(584) Underground Line Expenses
1,720,063
1,218,302
138.1
OperationOfEnergyStorageEquipmentDistribution
(584.1) Operation of Energy Storage Equipment
139
StreetLightingAndSignalSystemExpenses
(585) Street Lighting and Signal System Expenses
155,799
123,147
140
MeterExpenses
(586) Meter Expenses
2,075,232
2,791,566
141
CustomerInstallationsExpenses
(587) Customer Installations Expenses
779,122
656,839
142
MiscellaneousDistributionExpenses
(588) Miscellaneous Expenses
3,716,345
2,812,165
143
RentsDistributionExpense
(589) Rents
2,454,909
2,874,025
144
DistributionOperationExpensesElectric
TOTAL Operation (Enter Total of Lines 134 thru 143)
23,751,116
21,665,731
145
DistributionExpensesMaintenanceAbstract
Maintenance
146
MaintenanceSupervisionAndEngineering
(590) Maintenance Supervision and Engineering
974,260
913,865
147
MaintenanceOfStructuresDistributionExpense
(591) Maintenance of Structures
714,007
678,958
148
MaintenanceOfStationEquipment
(592) Maintenance of Station Equipment
1,052,921
1,023,179
148.1
MaintenanceOfEnergyStorageEquipment
(592.2) Maintenance of Energy Storage Equipment
149
MaintenanceOfOverheadLines
(593) Maintenance of Overhead Lines
29,873,238
27,056,662
150
MaintenanceOfUndergroundLines
(594) Maintenance of Underground Lines
1,143,003
980,781
151
MaintenanceOfLineTransformers
(595) Maintenance of Line Transformers
391,239
269,193
152
MaintenanceOfStreetLightingAndSignalSystems
(596) Maintenance of Street Lighting and Signal Systems
741,910
454,915
153
MaintenanceOfMeters
(597) Maintenance of Meters
42,883
86,080
154
MaintenanceOfMiscellaneousDistributionPlant
(598) Maintenance of Miscellaneous Distribution Plant
1,480,506
1,475,525
155
DistributionMaintenanceExpenseElectric
TOTAL Maintenance (Total of Lines 146 thru 154)
36,413,967
32,939,158
156
DistributionExpenses
TOTAL Distribution Expenses (Total of Lines 144 and 155)
60,165,083
54,604,889
157
CustomerAccountsExpensesAbstract
5. CUSTOMER ACCOUNTS EXPENSES
158
CustomerAccountsExpensesOperationsAbstract
Operation
159
SupervisionCustomerAccountExpenses
(901) Supervision
208,362
402,411
160
MeterReadingExpenses
(902) Meter Reading Expenses
3,178,288
5,065,550
161
CustomerRecordsAndCollectionExpenses
(903) Customer Records and Collection Expenses
19,322,183
14,467,811
162
UncollectibleAccounts
(904) Uncollectible Accounts
3,683,745
3,217,577
163
MiscellaneousCustomerAccountsExpenses
(905) Miscellaneous Customer Accounts Expenses
103,213
46,582
164
CustomerAccountExpenses
TOTAL Customer Accounts Expenses (Enter Total of Lines 159 thru 163)
26,495,791
23,199,931
165
CustomerServiceAndInformationalExpensesAbstract
6. CUSTOMER SERVICE AND INFORMATIONAL EXPENSES
166
CustomerServiceAndInformationalExpensesOperationAbstract
Operation
167
SupervisionCustomerServiceAndInformationExpenses
(907) Supervision
354,409
593,566
168
CustomerAssistanceExpenses
(908) Customer Assistance Expenses
3,822,364
11,375,343
169
InformationalAndInstructionalAdvertisingExpenses
(909) Informational and Instructional Expenses
811,223
531,566
170
MiscellaneousCustomerServiceAndInformationalExpenses
(910) Miscellaneous Customer Service and Informational Expenses
1,512,884
1,267,319
171
CustomerServiceAndInformationExpenses
TOTAL Customer Service and Information Expenses (Total Lines 167 thru 170)
6,500,880
13,767,794
172
SalesExpenseAbstract
7. SALES EXPENSES
173
SalesExpenseOperationAbstract
Operation
174
SupervisionSalesExpense
(911) Supervision
505
271
175
DemonstratingAndSellingExpenses
(912) Demonstrating and Selling Expenses
229,639
21,626
176
AdvertisingExpenses
(913) Advertising Expenses
898,185
1,118,442
177
MiscellaneousSalesExpenses
(916) Miscellaneous Sales Expenses
56,519
112,912
178
SalesExpenses
TOTAL Sales Expenses (Enter Total of Lines 174 thru 177)
1,184,848
1,253,251
179
AdministrativeAndGeneralExpensesAbstract
8. ADMINISTRATIVE AND GENERAL EXPENSES
180
AdministrativeAndGeneralExpensesOperationAbstract
Operation
181
AdministrativeAndGeneralSalaries
(920) Administrative and General Salaries
31,101,577
27,935,760
182
OfficeSuppliesAndExpenses
(921) Office Supplies and Expenses
1,363,669
1,237,435
183
AdministrativeExpensesTransferredCredit
(Less) (922) Administrative Expenses Transferred-Credit
184
OutsideServicesEmployed
(923) Outside Services Employed
17,097,225
13,927,359
185
PropertyInsurance
(924) Property Insurance
23,014,869
21,996,120
186
InjuriesAndDamages
(925) Injuries and Damages
2,148,906
5,952,199
187
EmployeePensionsAndBenefits
(926) Employee Pensions and Benefits
26,586,368
25,191,058
188
FranchiseRequirements
(927) Franchise Requirements
189
RegulatoryCommissionExpenses
(928) Regulatory Commission Expenses
3,071,197
4,049,545
190
DuplicateChargesCredit
(929) (Less) Duplicate Charges-Cr.
191
GeneralAdvertisingExpenses
(930.1) General Advertising Expenses
1,019,129
624,724
192
MiscellaneousGeneralExpenses
(930.2) Miscellaneous General Expenses
3,932,845
4,335,683
193
RentsAdministrativeAndGeneralExpense
(931) Rents
501,708
782,449
194
AdministrativeAndGeneralOperationExpense
TOTAL Operation (Enter Total of Lines 181 thru 193)
109,837,493
106,032,332
195
AdministrativeAndGeneralExpensesMaintenanceAbstract
Maintenance
196
MaintenanceOfGeneralPlant
(935) Maintenance of General Plant
1,322,449
1,250,864
197
AdministrativeAndGeneralExpenses
TOTAL Administrative & General Expenses (Total of Lines 194 and 196)
111,159,942
107,283,196
198
OperationsAndMaintenanceExpensesElectric
TOTAL Electric Operation and Maintenance Expenses (Total of Lines 80, 112, 131, 156, 164, 171, 178, and 197)
782,280,505
721,157,182


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
FOOTNOTE DATA

(a) Concept: FuelSteamPowerGeneration
Includes ($21,499,986) relating to certain gas hedging activities.
(b) Concept: FuelSteamPowerGeneration
Includes $8,359,880 relating to certain gas hedging activities.

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
PURCHASED POWER (Account 555)
  1. Report all power purchases made during the year. Also report exchanges of electricity (i.e., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges.
  2. Enter the name of the seller or other party in an exchange transaction in column (a). Do not abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the seller.
  3. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:

    RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (i.e., the supplier includes projects load for this service in its system resource planning). In addition, the reliability of requirement service must be the same as, or second only to, the supplier's service to its own ultimate consumers.

    LF - for long-term firm service. "Long-term" means five years or longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e.g., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for long-term firm service firm service which meets the definition of RQ service. For all transaction identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or seller can unilaterally get out of the contract.

    IF - for intermediate-term firm service. The same as LF service expect that "intermediate-term" means longer than one year but less than five years.

    SF - for short-term service. Use this category for all firm services, where the duration of each period of commitment for service is one year or less.

    LU - for long-term service from a designated generating unit. "Long-term" means five years or longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of the designated unit.

    IU - for intermediate-term service from a designated generating unit. The same as LU service expect that "intermediate-term" means longer than one year but less than five years.

    EX - For exchanges of electricity. Use this category for transactions involving a balancing of debits and credits for energy, capacity, etc. and any settlements for imbalanced exchanges.

    OS - for other service. Use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote for each adjustment.

    AD - for out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment.

  4. In column (c), identify the FERC Rate Schedule Number or Tariff, or, for non-FERC jurisdictional sellers, include an appropriate designation for the contract. On separate lines, list all FERC rate schedules, tariffs or contract designations under which service, as identified in column (b), is provided.
  5. For requirements RQ purchases and any type of service involving demand charges imposed on a monnthly (or longer) basis, enter the monthly average billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (f). For all other types of service, enter NA in columns (d), (e) and (f). Monthly NCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (f) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain.
  6. Report in column (g) the megawatthours shown on bills rendered to the respondent, excluding purchases for energy storage. Report in column (h) the megawatthours shown on bills rendered to the respondent for energy storage purchases. Report in columns (i) and (j) the megawatthours of power exchanges received and delivered, used as the basis for settlement. Do not report net exchange.
  7. Report demand charges in column (k), energy charges in column (l), and the total of any other types of charges, including out-of-period adjustments, in column (m). Explain in a footnote all components of the amount shown in column (m). Report in column (n) the total charge shown on bills received as settlement by the respondent. For power exchanges, report in column (n) the settlement amount for the net receipt of energy. If more energy was delivered than received, enter a negative amount. If the settlement amount (m) include credits or charges other than incremental generation expenses, or (2) excludes certain credits or charges covered by the agreement, provide an explanatory footnote.
  8. The data in columns (g) through (n) must be totaled on the last line of the schedule. The total amount in columns (g) and (h) must be reported as Purchases on Page 401, line 10. The total amount in column (i) must be reported as Exchange Received on Page 401, line 12. The total amount in column (j) must be reported as Exchange Delivered on Page 401, line 13.
  9. Footnote entries as required and provide explanations following all required data.
Actual Demand (MW) POWER EXCHANGES COST/SETTLEMENT OF POWER
Line No.
NameOfCompanyOrPublicAuthorityProvidingPurchasedPower
Name of Company or Public Authority (Footnote Affiliations)
(a)
StatisticalClassificationCode
Statistical Classification
(b)
RateScheduleTariffNumber
Ferc Rate Schedule or Tariff Number
(c)
AverageMonthlyBillingDemand
Average Monthly Billing Demand (MW)
(d)
AverageMonthlyNonCoincidentPeakDemand
Average Monthly NCP Demand
(e)
AverageMonthlyCoincidentPeakDemand
Average Monthly CP Demand
(f)
MegawattHoursPurchasedOtherThanStorage
MegaWatt Hours Purchased (Excluding for Energy Storage)
(g)
MegawattHoursPurchasedForEnergyStorage
MegaWatt Hours Purchased for Energy Storage
(h)
EnergyReceivedThroughPowerExchanges
MegaWatt Hours Received
(i)
EnergyDeliveredThroughPowerExchanges
MegaWatt Hours Delivered
(j)
DemandChargesOfPurchasedPower
Demand Charges ($)
(k)
EnergyChargesOfPurchasedPower
Energy Charges ($)
(l)
OtherChargesOfPurchasedPower
Other Charges ($)
(m)
SettlementOfPower
Total (k+l+m) of Settlement ($)
(n)
1
Energy System Power Pool
2
(a)
System Energy Resources, Inc.
3,495,832
165,760,833
19,243,421
(c)
3,760,835
188,765,089
3
(b)
Entergy Arkansas, LLC
735,998
34,890,845
4,051,465
38,942,310
4
Terra Miss Nitrogen
29
1,123
1,123
5
CF Industries Nitrogen, LLC
6,485
174,799
174,799
6
Midcontinent ISO, Inc.
1,686,007
733
74,121,232
(d)
4,043,148
70,077,351
7
Small Residential Generation
996
29,283
29,283
8
EDF Trading North America, LLC
(e)
22,058
22,058
15 TOTAL
5,925,347
0
0
0
200,650,945
97,621,323
304,371
297,967,897


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
FOOTNOTE DATA

(a) Concept: NameOfCompanyOrPublicAuthorityProvidingPurchasedPower
Energy and capacity charges from the Grand Gulf Nuclear Power Plant.
(b) Concept: NameOfCompanyOrPublicAuthorityProvidingPurchasedPower
Energy and capacity charges associated with MSS-4.
(c) Concept: OtherChargesOfPurchasedPower
Represents $14,072,098 for deferral on over/under recovery under the Grand Gulf Rider and ($10,311,263) for the turnaround of the Grand Gulf Accelerated Recovery Tariff approved by the FERC that provided for the acceleration of Entergy Arkansas's and Entergy Mississippi's Grand Gulf purchased power obligations with System Energy Resources.
(d) Concept: OtherChargesOfPurchasedPower
CHARGES
MISO Ancillary $1,873,470 
MISO Congestion (10,631,799)
MISO Losses (2,253,925)
MISO Residual Load 441,009 
MISO Uplift 6,340,943 
MISO Administration 187,154 
Total Other Purchases from MISO ($4,043,148)
(e) Concept: OtherChargesOfPurchasedPower
Related to the sale of Entergy Mississippi's Auction Revenue Rights allocated to Entergy Mississippi as part of its participation in MISO.

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")
  1. Report all transmission of electricity, i.e., wheeling, provided for other electric utilities, cooperatives, other public authorities, qualifying facilities, non-traditional utility suppliers and ultimate customers for the quarter.
  2. Use a separate line of data for each distinct type of transmission service involving the entities listed in column (a), (b) and (c).
  3. Report in column (a) the company or public authority that paid for the transmission service. Report in column (b) the company or public authority that the energy was received from and in column (c) the company or public authority that the energy was delivered to. Provide the full name of each company or public authority. Do not abbreviate or truncate name or use acronyms. Explain in a footnote any ownership interest in or affiliation the respondent has with the entities listed in columns (a), (b) or (c).
  4. In column (d) enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows: FNO - Firm Network Service for Others, FNS - Firm Network Transmission Service for Self, LFP - "Long-Term Firm Point to Point Transmission Service, OLF - Other Long-Term Firm Transmission Service, SFP - Short-Term Firm Point to Point Transmission Reservation, NF - non-firm transmission service, OS - Other Transmission Service and AD - Out-of-Period Adjustments. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting periods. Provide an explanation in a footnote for each adjustment. See General Instruction for definitions of codes.
  5. In column (e), identify the FERC Rate Schedule or Tariff Number, On separate lines, list all FERC rate schedules or contract designations under which service, as identified in column (d), is provided.
  6. Report receipt and delivery locations for all single contract path, "point to point" transmission service. In column (f), report the designation for the substation, or other appropriate identification for where energy was received as specified in the contract. In column (g) report the designation for the substation, or other appropriate identification for where energy was delivered as specified in the contract.
  7. Report in column (h) the number of megawatts of billing demand that is specified in the firm transmission service contract. Demand reported in column (h) must be in megawatts. Footnote any demand not stated on a megawatts basis and explain.
  8. Report in column (i) and (j) the total megawatthours received and delivered.
  9. In column (k) through (n), report the revenue amounts as shown on bills or vouchers. In column (k), provide revenues from demand charges related to the billing demand reported in column (h). In column (I), provide revenues from energy charges related to the amount of energy transferred. In column (m), provide the total revenues from all other charges on bills or vouchers rendered, including out of period adjustments. Explain in a footnote all components of the amount shown in column (m). Report in column (n) the total charge shown on bills rendered to the entity Listed in column (a). If no monetary settlement was made, enter zero (0) in column (n). Provide a footnote explaining the nature of the non-monetary settlement, including the amount and type of energy or service rendered.
  10. The total amounts in columns (i) and (j) must be reported as Transmission Received and Transmission Delivered for annual report purposes only on Page 401, Lines 16 and 17, respectively.
  11. Footnote entries and provide explanations following all required data.
TRANSFER OF ENERGY REVENUE FROM TRANSMISSION OF ELECTRICITY FOR OTHERS
Line No.
PaymentByCompanyOrPublicAuthority
Payment By (Company of Public Authority) (Footnote Affiliation)
(a)
TransmissionEnergyReceivedFromCompanyOrPublicAuthorityName
Energy Received From (Company of Public Authority) (Footnote Affiliation)
(b)
TransmissionEnergyDeliveredToCompanyOrPublicAuthorityName
Energy Delivered To (Company of Public Authority) (Footnote Affiliation)
(c)
StatisticalClassificationCode
Statistical Classification
(d)
RateScheduleTariffNumber
Ferc Rate Schedule of Tariff Number
(e)
TransmissionPointOfReceipt
Point of Receipt (Substation or Other Designation)
(f)
TransmissionPointOfDelivery
Point of Delivery (Substation or Other Designation)
(g)
BillingDemand
Billing Demand (MW)
(h)
TransmissionOfElectricityForOthersEnergyReceived
Megawatt Hours Received
(i)
TransmissionOfElectricityForOthersEnergyDelivered
Megawatt Hours Delivered
(j)
Demand Charges ($)
(k)
Energy Charges ($)
(l)
Other Charges ($)
(m)
RevenuesFromTransmissionOfElectricityForOthers
Total Revenues ($) (k+l+m)
(n)
1
MISO
Various
Various
Various
Various
40,263,484
40,263,484
35 TOTAL
0
0
0
40,263,484
40,263,484


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
TRANSMISSION OF ELECTRICITY BY ISO/RTOs
  1. Report in Column (a) the Transmission Owner receiving revenue for the transmission of electricity by the ISO/RTO.
  2. Use a separate line of data for each distinct type of transmission service involving the entities listed in Column (a).
  3. In Column (b) enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows: FNO – Firm Network Service for Others, FNS – Firm Network Transmission Service for Self, LFP – Long-Term Firm Point-to-Point Transmission Service, OLF – Other Long-Term Firm Transmission Service, SFP – Short-Term Firm Point-to-Point Transmission Reservation, NF – Non-Firm Transmission Service, OS – Other Transmission Service and AD- Out-of-Period Adjustments. Use this code for any accounting adjustments or “true-ups” for service provided in prior reporting periods. Provide an explanation in a footnote for each adjustment. See General Instruction for definitions of codes.
  4. In column (c) identify the FERC Rate Schedule or tariff Number, on separate lines, list all FERC rate schedules or contract designations under which service, as identified in column (b) was provided.
  5. In column (d) report the revenue amounts as shown on bills or vouchers.
  6. Report in column (e) the total revenues distributed to the entity listed in column (a).
Line No.
Payment Received by (Transmission Owner Name)
(a)
Statistical Classification
(b)
FERC Rate Schedule or Tariff Number
(c)
Total Revenue by Rate Schedule or Tariff
(d)
Total Revenue
(e)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47
48
49
40
TOTAL


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
TRANSMISSION OF ELECTRICITY BY OTHERS (Account 565)
  1. Report all transmission, i.e. wheeling or electricity provided by other electric utilities, cooperatives, municipalities, other public authorities, qualifying facilities, and others for the quarter.
  2. In column (a) report each company or public authority that provided transmission service. Provide the full name of the company, abbreviate if necessary, but do not truncate name or use acronyms. Explain in a footnote any ownership interest in or affiliation with the transmission service provider. Use additional columns as necessary to report all companies or public authorities that provided transmission service for the quarter reported.
  3. In column (b) enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows:
    FNS - Firm Network Transmission Service for Self, LFP - Long-Term Firm Point-to-Point Transmission Reservations. OLF - Other Long-Term Firm Transmission Service, SFP - Short-Term Firm Point-to- Point Transmission Reservations, NF - Non-Firm Transmission Service, and OS - Other Transmission Service. See General Instructions for definitions of statistical classifications.
  4. Report in column (c) and (d) the total megawatt hours received and delivered by the provider of the transmission service.
  5. Report in column (e), (f) and (g) expenses as shown on bills or vouchers rendered to the respondent. In column (e) report the demand charges and in column (f) energy charges related to the amount of energy transferred. On column (g) report the total of all other charges on bills or vouchers rendered to the respondent, including any out of period adjustments. Explain in a footnote all components of the amount shown in column (g). Report in column (h) the total charge shown on bills rendered to the respondent. If no monetary settlement was made, enter zero in column (h). Provide a footnote explaining the nature of the non-monetary settlement, including the amount and type of energy or service rendered.
  6. Enter ""TOTAL"" in column (a) as the last line.
  7. Footnote entries and provide explanations following all required data.
TRANSFER OF ENERGY EXPENSES FOR TRANSMISSION OF ELECTRICITY BY OTHERS
Line No.
NameOfCompanyOrPublicAuthorityTransmissionOfElectricityByOthers
Name of Company or Public Authority (Footnote Affiliations)
(a)
StatisticalClassificationCode
Statistical Classification
(b)
TransmissionOfElectricityByOthersEnergyReceived
MegaWatt Hours Received
(c)
TransmissionOfElectricityByOthersEnergyDelivered
MegaWatt Hours Delivered
(d)
DemandChargesTransmissionOfElectricityByOthers
Demand Charges ($)
(e)
EnergyChargesTransmissionOfElectricityByOthers
Energy Charges ($)
(f)
OtherChargesTransmissionOfElectricityByOthers
Other Charges ($)
(g)
ChargesForTransmissionOfElectricityByOthers
Total Cost of Transmission ($)
(h)
1
Midcontinent Independent System Operator Inc
(a)
7,720,535
(b)
11,458
7,731,993
TOTAL
0
0
7,720,535
0
11,458
7,731,993


FOOTNOTE DATA

(a) Concept: DemandChargesTransmissionOfElectricityByOthers
The Utility operating companies are transmission owning members of the Midcontinent Independent System Operator (MISO) RTO. MISO is the transmission provider under the MISO Attachment O. Entergy Mississippi incurred charges from MISO for the purchase of network transmission service under the MISO Attachment O. MISO calculated the network service charges applicable to Entergy Mississippi and billed the entity for such service.
(b) Concept: OtherChargesTransmissionOfElectricityByOthers
Network upgrade charges incurred from MISO under the MISO Attachment O. Rates are calculated under Attachment GG. Charges are related to the MTEP (MISO Transmission Expansion Plan).

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
MISCELLANEOUS GENERAL EXPENSES (Account 930.2) (ELECTRIC)
Line No.
Description
(a)
Amount
(b)
1
IndustryAssociationDues
Industry Association Dues
496,189
2
NuclearPowerResearchExpenses
Nuclear Power Research Expenses
3
OtherExperimentalAndGeneralResearchExpenses
Other Experimental and General Research Expenses
4
PublicationAndDistributionExpensesForSecuritiesToStockholders
Pub and Dist Info to Stkhldrs...expn servicing outstanding Securities
307,835
5
OtherMiscellaneousGeneralExpenses
Oth Expn greater than or equal to 5,000 show purpose, recipient, amount. Group if less than $5,000
6
5% surcharge on regulated billings to non-regulated affiliates
401,740
7
Directors meetings and expenses
60,035
8
Section 263A research - tax services
15,701
9
System aircraft
335,873
10
Corporate purchasing card rebates
62,783
11
IT hardware applications/service contracts
3,170,041
12
Mobile device services
7,414
13
HR leadership development
13,885
14
Travel to reimburse project
9,520
15
Other
85
46
MiscellaneousGeneralExpenses
TOTAL
3,932,845


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
Depreciation and Amortization of Electric Plant (Account 403, 404, 405)
  1. Report in section A for the year the amounts for: (b) Depreciation Expense (Account 403); (c) Depreciation Expense for Asset Retirement Costs (Account 403.1); (d) Amortization of Limited-Term Electric Plant (Account 404); and (e) Amortization of Other Electric Plant (Account 405).
  2. Report in Section B the rates used to compute amortization charges for electric plant (Accounts 404 and 405). State the basis used to compute charges and whether any changes have been made in the basis or rates used from the preceding report year.
  3. Report all available information called for in Section C every fifth year beginning with report year 1971, reporting annually only changes to columns (c) through (g) from the complete report of the preceding year.
    Unless composite depreciation accounting for total depreciable plant is followed, list numerically in column (a) each plant subaccount, account or functional classification, as appropriate, to which a rate is applied. Identify at the bottom of Section C the type of plant included in any sub-account used.
    In column (b) report all depreciable plant balances to which rates are applied showing subtotals by functional Classifications and showing composite total. Indicate at the bottom of section C the manner in which column balances are obtained. If average balances, state the method of averaging used.
    For columns (c), (d), and (e) report available information for each plant subaccount, account or functional classification listed in column (a). If plant mortality studies are prepared to assist in estimating average service Lives, show in column (f) the type of mortality curve selected as most appropriate for the account and in column (g), if available, the weighted average remaining life of surviving plant. If composite depreciation accounting is used, report available information called for in columns (b) through (g) on this basis.
  4. If provisions for depreciation were made during the year in addition to depreciation provided by application of reported rates, state at the bottom of section C the amounts and nature of the provisions and the plant items to which related.
A. Summary of Depreciation and Amortization Charges
Line No.
FunctionalClassificationAxis
Functional Classification
(a)
DepreciationExpenseExcludingAmortizationOfAcquisitionAdjustments
Depreciation Expense (Account 403)
(b)
DepreciationExpenseForAssetRetirementCostsExcludingAmortizationgOfAcquisitionAdjustments
Depreciation Expense for Asset Retirement Costs (Account 403.1)
(c)
AmortizationOfLimitedTermPlantOrProperty
Amortization of Limited Term Electric Plant (Account 404)
(d)
AmortizationOfOtherElectricPlant
Amortization of Other Electric Plant (Acc 405)
(e)
DepreciationAndAmortization
Total
(f)
1
Intangible Plant
20,508,961
20,508,961
2
Steam Production Plant
30,760,115
11,486
30,771,601
3
Nuclear Production Plant
4
Hydraulic Production Plant-Conventional
5
Hydraulic Production Plant-Pumped Storage
6
Other Production Plant
26,505,836
26,505,836
7
Transmission Plant
40,378,280
40,378,280
8
Distribution Plant
83,524,388
83,524,388
9
Regional Transmission and Market Operation
10
General Plant
(a)
21,748,967
21,748,967
11
Common Plant-Electric
12
TOTAL
202,917,586
11,486
20,508,961
223,438,033
B. Basis for Amortization Charges
C. Factors Used in Estimating Depreciation Charges
Line No.
AccountNumberFactorsUsedInEstimatingDepreciationCharges
Account No.
(a)
DepreciablePlantBase
Depreciable Plant Base (in Thousands)
(b)
UtilityPlantEstimatedAverageServiceLife
Estimated Avg. Service Life
(c)
UtilityPlantNetSalvageValuePercentage
Net Salvage (Percent)
(d)
UtilityPlantAppliedDepreciationRate
Applied Depr. Rates (Percent)
(e)
MortalityCurveType
Mortality Curve Type
(f)
UtilityPlantWeightedAverageRemainingLife
Average Remaining Life
(g)
12
0.001
57 years
14.84
SQ
4 years, 8 months
13
0.731
57 years
38
8.32
R2.5
4 years, 7 months
14
5.538
57 years
38
10.77
R2.5
4 years, 7 months
15
2.546
57 years
38
12.65
R0.5
4 years, 6 months
16
0.46
57 years
38
2.74
O1
4 years, 6 months
17
5.104
57 years
38
12.61
R1.5
4 years, 6 months
18
2.666
57 years
38
16.77
R1
4 years, 7 months
19
6.608
57 years
38
12.12
R2.5
4 years, 7 months
20
32.168
57 years
38
4.3
R0.5
4 years, 6 months
21
37.925
57 years
38
13.66
O1
4 years, 6 months
22
5.279
57 years
38
19.15
R1.5
4 years, 6 months
23
0.303
57 years
38
19.56
R1
4 years, 6 months
24
0.001
1.87
25
0.04
1.18
26
0.004
61 years
3.98
SQ
16 years, 6 months
27
27.842
61 years
13
1.24
R2.5
16 years, 2 months
28
61 years
13
0.79
R2.5
16 years, 2 months
29
90.879
61 years
13
3.39
R0.5
15 years, 10 months
30
35.451
61 years
13
3.26
O1
15 years, 7 months
31
15.717
61 years
13
3.35
15 years, 11 months
32
2.812
61 years
13
2.6
R1
16 years, 2 months
33
0.02
45 years
1.14
16 years, 7 months
34
0.375
45 years
13
1.94
16 years, 4 months
35
0.012
45 years
13
36
2.169
47 years
8
1.98
R2.5
11 years, 6 months
37
17.609
47 years
8
2.58
R0.5
11 years, 4 months
38
0.406
47 years
8
2.58
R0.5
11 years, 4 months
39
0.253
47 years
8
1.67
O1
11 years, 1 month
40
0.63
47 years
8
2.77
R1.5
11 years, 5 months
41
1.707
47 years
8
2.03
R1
11 years, 5 months
42
16.229
47 years
9
2.73
R2.5
11 years, 5 months
43
85.415
47 years
9
4.28
R0.5
11 years, 2 months
44
23.529
47 years
6
1.45
O1
11 years, 1 month
45
12.733
47 years
9
1.54
R1.5
11 years, 2 months
46
2.1
47 years
6
1.51
R1
11 years, 4 months
47
3.892
47 years
9
0.35
R2.5
11 years, 5 months
48
80.037
47 years
9
4.52
R0.5
11 years, 2 months
49
26.039
47 years
6
1.52
O1
11 years, 1 month
50
6.762
47 years
9
1.71
R1.5
11 years, 4 months
51
0.287
47 years
6
1.73
R1
11 years, 5 months
52
0.04
4.93
53
0.005
71 years
7.23
10 years
54
0.104
71 years
5.29
10 years
55
0.265
71 years
7.13
10 years
56
0.005
4.22
57
2.403
10
58
0.401
10
59
0.019
10
60
0.371
10
61
0.205
10
62
0.266
10
63
0.164
10
64
0.258
10
65
0.057
10
66
0.261
10
67
0.179
10
68
0.189
10
69
0.091
10
70
0.023
10
71
0.655
10
72
2.285
10
73
1.509
10
74
0.703
10
75
0.26
10
76
0.016
10
77
0.079
10
78
0.105
10
79
0.022
10
80
0.031
10
81
0.033
10
82
0.294
10
83
0.196
10
84
0.098
10
85
0.033
10
86
6.314
35 years
3.33
SQ
17 years, 7 months
87
1.369
35 years
3.33
SQ
17 years, 7 months
88
0.274
35 years
3.33
R0.5
13 years, 5 months
89
0.613
35 years
3.33
L0.5
15 years, 2 months
90
1.471
35 years
3.33
L0
16 years
91
1.601
35 years
3.33
R0.5
13 years, 10 months
92
9.951
35 years
3.33
SQ
17 years, 7 months
93
2.148
35 years
3.33
SQ
17 years, 7 months
94
46.373
35 years
3.33
R0.5
14 years
95
44.797
35 years
3.33
L0.5
15 years, 2 months
96
12.896
35 years
3.33
L0
15 years, 11 months
97
0.909
35 years
3.33
R0.5
14 years, 2 months
98
2.761
99
18.843
4.55
100
2.829
4.55
101
208.856
4.55
102
49.024
4.55
103
20.741
4.55
104
0.93
4.55
105
15.462
35 years
3.33
SQ
17 years, 7 months
106
0.196
35 years
3.33
SQ
17 years, 7 months
107
52.284
35 years
3.33
R0.5
14 years, 10 months
108
131.766
35 years
3.33
L0.5
15 years, 7 months
109
3.219
35 years
3.33
L0
16 years, 2 months
110
2.278
35 years
3.33
R0.5
14 years, 7 months
111
4.31
3.33
SQ
112
2.108
3.33
SQ
113
25.584
3.33
SQ
114
4.966
3.33
SQ
115
7.654
3.33
SQ
116
0.856
3.33
SQ
117
1.552
20 years
5
SQ
17 years
118
1.416
20 years
5
SQ
17 years
119
1.594
20 years
5
SQ
17 years
120
83.165
75 years
2.62
S5
27 years, 6 months
121
62.983
70 years
10
1.89
R3
51 years, 2 months
122
708.018
55 years
1.83
R2
42 years, 5 months
123
56.66
65 years
40
2.28
R4
30 years, 5 months
124
485.534
60 years
85
3.45
R2
52 years, 5 months
125
275.936
70 years
50
2.59
R1.5
56 years, 2 months
126
6.265
70 years
50
2.59
R1.5
56 years, 2 months
127
45.521
70 years
50
2.59
R1.5
56 years, 2 months
128
0.001
60 years
1.66
S2
43 years, 11 months
129
0.006
55 years
1.8
S2
39 years, 4 months
130
4.632
75 years
1.27
S5
42 years, 11 months
131
19.548
60 years
10
1.83
R4
43 years, 5 months
132
391.499
70 years
2.06
R1.5
57 years, 1 month
133
411.774
36 years
25
3.75
R0.5
28 years, 6 months
134
445.408
45 years
25
3.57
O1
38 years, 5 months
135
1.175
45 years
25
3.57
O1
38 years, 5 months
136
55.021
45 years
25
3.57
O1
38 years, 5 months
137
51.451
60 years
20
2.06
R2
50 years, 5 months
138
103.371
60 years
1.64
R1
49 years, 5 months
139
605.664
28 years
15
4.17
R1.5
20 years, 2 months
140
136.301
40 years
25
3.29
R2
29 years, 10 months
141
54.176
42 years
25
2.45
R2
31 years, 1 month
142
6.263
5
3.26
3 years, 1 month
143
0.025
3.26
144
111.058
15 years
6.67
SQ
15 years
145
41.775
25 years
5
2.24
L0
18 years, 11 months
146
86.116
25 years
10
4.19
R1
17 years, 11 months
147
0.034
30 years
5
3.44
R1.5
28 years, 11 months
148
20
149
0.001
75 years
1.72
S5
50 years, 4 months
150
113.147
55 years
10
2.28
R2.5
42 years, 2 months
151
0.035
55 years
R2.5
42 years, 2 months
152
1.028
15 years
6.67
SQ
13 years, 11 months
153
19.031
5 years
20
SQ
3 years, 8 months
154
0.372
15 years
6.67
SQ
12 years
155
0.262
5 years
20
SQ
3 years, 5 months
156
0.012
6.67
157
7.492
15 years
6.67
SQ
13 years, 2 months
158
4.412
10 years
10
SQ
8 years
159
0.064
6.67
160
21.335
10 years
10
SQ
7 years, 4 months
161
6.67
10 years
10
SQ
7 years, 6 months
162
1.676
10 years
10
SQ
7 years, 4 months
163
1.556
10
164
7.308
10
165
0.655
10
166
0.076
10
167
0.664
10
168
3.886
10
169
0.195
10
170
0.327
10
171
1.998
10
172
8.685
10
173
0.518
10


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
FOOTNOTE DATA

(a) Concept: DepreciationExpenseExcludingAmortizationOfAcquisitionAdjustments
Includes $3,207,943 of service company depreciation billing allocations.
(b) Concept: AccountNumberFactorsUsedInEstimatingDepreciationCharges
General plant contra amounts are not included by location.
(c) Concept: AccountNumberFactorsUsedInEstimatingDepreciationCharges
General plant contra amounts are not included by location.
(d) Concept: AccountNumberFactorsUsedInEstimatingDepreciationCharges
General plant contra amounts are not included by location.
(e) Concept: AccountNumberFactorsUsedInEstimatingDepreciationCharges
General plant contra amounts are not included by location.
(f) Concept: AccountNumberFactorsUsedInEstimatingDepreciationCharges
General plant contra amounts are not included by location.
(g) Concept: AccountNumberFactorsUsedInEstimatingDepreciationCharges
General plant contra amounts are not included by location.
(h) Concept: AccountNumberFactorsUsedInEstimatingDepreciationCharges
General plant contra amounts are not included by location.
(i) Concept: AccountNumberFactorsUsedInEstimatingDepreciationCharges
General plant contra amounts are not included by location.
(j) Concept: AccountNumberFactorsUsedInEstimatingDepreciationCharges
General plant contra amounts are not included by location.
(k) Concept: AccountNumberFactorsUsedInEstimatingDepreciationCharges
General plant contra amounts are not included by location.
(l) Concept: AccountNumberFactorsUsedInEstimatingDepreciationCharges
General plant contra amounts are not included by location.

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
REGULATORY COMMISSION EXPENSES
  1. Report particulars (details) of regulatory commission expenses incurred during the current year (or incurred in previous years, if being amortized) relating to format cases before a regulatory body, or cases in which such a body was a party.
  2. Report in columns (b) and (c), only the current year's expenses that are not deferred and the current year's amortization of amounts deferred in previous years.
  3. Show in column (k) any expenses incurred in prior years which are being amortized. List in column (a) the period of amortization.
  4. List in columns (f), (g), and (h), expenses incurred during the year which were charged currently to income, plant, or other accounts.
  5. Minor items (less than $25,000) may be grouped.
EXPENSES INCURRED DURING YEAR AMORTIZED DURING YEAR
CURRENTLY CHARGED TO
Line No.
RegulatoryCommissionDescription
Description (Furnish name of regulatory commission or body the docket or case number and a description of the case)
(a)
RegulatoryExpensesAssessedByRegulatoryCommission
Assessed by Regulatory Commission
(b)
RegulatoryExpensesOfUtility
Expenses of Utility
(c)
RegulatoryCommissionExpensesAmount
Total Expenses for Current Year
(d)
OtherRegulatoryAssetsRegulatoryCommissionExpenses
Deferred in Account 182.3 at Beginning of Year
(e)
NameOfDepartmentRegulatoryCommissionExpensesCharged
Department
(f)
AccountNumberRegulatoryCommissionExpensesCharged
Account No.
(g)
RegulatoryComissionExpensesIncurredAndCharged
Amount
(h)
RegulatoryCommissionExpensesDeferredToOtherRegulatoryAssets
Deferred to Account 182.3
(i)
DeferredRegulatoryCommissionExpensesAmortizedInContraAccount
Contra Account
(j)
DeferredRegulatoryCommissionExpensesAmortized
Amount
(k)
OtherRegulatoryAssetsRegulatoryCommissionExpenses
Deferred in Account 182.3 End of Year
(l)
1
Other expenses incurred in connection wiht various filings before the FERC
196,413
196,413
Electric
196,413
2
Other expenses incurred in connection with MISO and other transmission related FERC dockets
4,666
4,666
Electric
4,666
3
MPSC  - Docket No. 2017-UA-189 - MISO Renewal Cost Benefit Analysis
859,016
859,016
Electric
859,016
4
MPSC  - Docket No. 2008-UN-381 - Power Management Rider Expense
343
343
Electric
343
5
MPSC  - Docket No. 2009-UN-388 - Attorney General Litigation
67,082
67,082
358,413
67,082
291,331
6
MPSC  - Docket No. 2018-UN-205 - EML Formula Rate Plan
642,219
642,219
Electric
642,218
7
MPSC - Docket No. 2010-AD-2 - MS EE Comprehensive Portfolio Program
165
165
Electric
165
8
Other expenses incurred in connection with various filings before the MPSC
1,301,293
1,301,293
Electric
1,301,293
46
TOTAL
3,071,197
3,071,197
358,413
3,004,114
67,082
291,331


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
RESEARCH, DEVELOPMENT, AND DEMONSTRATION ACTIVITIES
  1. Describe and show below costs incurred and accounts charged during the year for technological research, development, and demonstration (R, D and D) project initiated, continued or concluded during the year. Report also support given to others during the year for jointly-sponsored projects.(Identify recipient regardless of affiliation.) For any R, D and D work carried with others, show separately the respondent's cost for the year and cost chargeable to others (See definition of research, development, and demonstration in Uniform System of Accounts).
  2. Indicate in column (a) the applicable classification, as shown below:
    Classifications:
    1. Electric R, D and D Performed Internally:
      1. Generation
        1. hydroelectric
          1. Recreation fish and wildlife
          2. Other hydroelectric
        2. Fossil-fuel steam
        3. Internal combustion or gas turbine
        4. Nuclear
        5. Unconventional generation
        6. Siting and heat rejection
      2. Transmission
        1. Overhead
        2. Underground
      3. Distribution
      4. Regional Transmission and Market Operation
      5. Environment (other than equipment)
      6. Other (Classify and include items in excess of $50,000.)
      7. Total Cost Incurred
    2. Electric, R, D and D Performed Externally:
      1. Research Support to the electrical Research Council or the Electric Power Research Institute
      2. Research Support to Edison Electric Institute
      3. Research Support to Nuclear Power Groups
      4. Research Support to Others (Classify)
      5. Total Cost Incurred
  3. Include in column (c) all R, D and D items performed internally and in column (d) those items performed outside the company costing $50,000 or more, briefly describing the specific area of R, D and D (such as safety, corrosion control, pollution, automation, measurement, insulation, type of appliance, etc.). Group items under $50,000 by classifications and indicate the number of items grouped. Under Other, (A (6) and B (4)) classify items by type of R, D and D activity.
  4. Show in column (e) the account number charged with expenses during the year or the account to which amounts were capitalized during the year, listing Account 107, Construction Work in Progress, first. Show in column (f) the amounts related to the account charged in column (e).
  5. Show in column (g) the total unamortized accumulating of costs of projects. This total must equal the balance in Account 188, Research, Development, and Demonstration Expenditures, Outstanding at the end of the year.
  6. If costs have not been segregated for R, D and D activities or projects, submit estimates for columns (c), (d), and (f) with such amounts identified by ""Est.""
  7. Report separately research and related testing facilities operated by the respondent.
AMOUNTS CHARGED IN CURRENT YEAR
Line No.
ResearchDevelopmentAndDemonstrationClassification
Classification
(a)
ResearchDevelopmentAndDemonstrationDescription
Description
(b)
ResearchDevelopmentAndDemonstrationCostsIncurredInternally
Costs Incurred Internally Current Year
(c)
ResearchDevelopmentAndDemonstrationCostsIncurredExternally
Costs Incurred Externally Current Year
(d)
AccountNumberForResearchDevelopmentAndDemonstrationCosts
Amounts Charged In Current Year: Account
(e)
ResearchDevelopmentAndDemonstrationCosts
Amounts Charged In Current Year: Amount
(f)
ResearchDevelopmentAndDemonstrationExpenditures
Unamortized Accumulation
(g)
1
A(3) B(4)
Advanced meters
262,371
120
262,491
2
A(3)
Distribution Automation
9,493
9,493
3
B(4)
Transmission University Research
10,212
10,212
4
B(4)
Environmental Research
29,175
29,175
5
B(1)
EPRI dues 1
70,359
70,359
6
B(1)
EPRI dues 2
76,637
76,637
7
B(1)
EPRI dues 3
307,686
307,686
8
B(1)
EPRI dues 4
79,808
79,808
9
B(2)
Edison Electric Institute
248,166
248,166
10
B(4)
SERC Dues
488,900
488,900
11
B(4)
CEATI International
14,281
14,281


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
DISTRIBUTION OF SALARIES AND WAGES

Report below the distribution of total salaries and wages for the year. Segregate amounts originally charged to clearing accounts to Utility Departments, Construction, Plant Removals, and Other Accounts, and enter such amounts in the appropriate lines and columns provided. In determining this segregation of salaries and wages originally charged to clearing accounts, a method of approximation giving substantially correct results may be used.

Line No.
Classification
(a)
Direct Payroll Distribution
(b)
Allocation of Payroll Charged for Clearing Accounts
(c)
Total
(d)
1
SalariesAndWagesElectricAbstract
Electric
2
SalariesAndWagesElectricOperationAbstract
Operation
3
SalariesAndWagesElectricOperationProduction
Production
12,878,424
4
SalariesAndWagesElectricOperationTransmission
Transmission
853,388
5
SalariesAndWagesElectricOperationRegionalMarket
Regional Market
6,080,624
6
SalariesAndWagesElectricOperationDistribution
Distribution
2,876,125
7
SalariesAndWagesElectricOperationCustomerAccounts
Customer Accounts
1,885,502
8
SalariesAndWagesElectricOperationCustomerServiceAndInformational
Customer Service and Informational
9
SalariesAndWagesElectricOperationSales
Sales
10
SalariesAndWagesElectricOperationAdministrativeAndGeneral
Administrative and General
6,016,071
11
SalariesAndWagesElectricOperation
TOTAL Operation (Enter Total of lines 3 thru 10)
30,590,134
12
SalariesAndWagesElectricMaintenanceAbstract
Maintenance
13
SalariesAndWagesElectricMaintenanceProduction
Production
7,253,998
14
SalariesAndWagesElectricMaintenanceTransmission
Transmission
2,291,281
15
SalariesAndWagesElectricMaintenanceRegionalMarket
Regional Market
16
SalariesAndWagesElectricMaintenanceDistribution
Distribution
5,712,047
17
SalariesAndWagesElectricMaintenanceAdministrativeAndGeneral
Administrative and General
261,759
18
SalariesAndWagesElectricMaintenance
TOTAL Maintenance (Total of lines 13 thru 17)
15,519,085
19
SalariesAndWagesElectricOperationAndMaintenanceAbstract
Total Operation and Maintenance
20
SalariesAndWagesElectricProduction
Production (Enter Total of lines 3 and 13)
20,132,422
21
SalariesAndWagesElectricTransmission
Transmission (Enter Total of lines 4 and 14)
3,144,669
22
SalariesAndWagesElectricRegionalMarket
Regional Market (Enter Total of Lines 5 and 15)
6,080,624
23
SalariesAndWagesElectricDistribution
Distribution (Enter Total of lines 6 and 16)
8,588,172
24
SalariesAndWagesElectricCustomerAccounts
Customer Accounts (Transcribe from line 7)
1,885,502
25
SalariesAndWagesElectricCustomerServiceAndInformational
Customer Service and Informational (Transcribe from line 8)
26
SalariesAndWagesElectricSales
Sales (Transcribe from line 9)
27
SalariesAndWagesElectricAdministrativeAndGeneral
Administrative and General (Enter Total of lines 10 and 17)
6,277,830
28
SalariesAndWagesElectricOperationAndMaintenance
TOTAL Oper. and Maint. (Total of lines 20 thru 27)
46,109,219
46,109,219
29
SalariesAndWagesGasAbstract
Gas
30
SalariesAndWagesGasOperationAbstract
Operation
31
SalariesAndWagesGasOperationProductionManufacturedGas
Production - Manufactured Gas
32
SalariesAndWagesGasOperationProductionNaturalGas
Production-Nat. Gas (Including Expl. And Dev.)
33
SalariesAndWagesGasOperationOtherGasSupply
Other Gas Supply
34
SalariesAndWagesGasOperationStorageLiquifiedNaturalGasTerminalingAndProcessing
Storage, LNG Terminaling and Processing
35
SalariesAndWagesGasOperationTransmission
Transmission
36
SalariesAndWagesGasOperationDistribution
Distribution
37
SalariesAndWagesGasCustomerAccounts
Customer Accounts
38
SalariesAndWagesGasCustomerServiceAndInformational
Customer Service and Informational
39
SalariesAndWagesGasSales
Sales
40
SalariesAndWagesGasOperationAdministrativeAndGeneral
Administrative and General
41
SalariesAndWagesGasOperation
TOTAL Operation (Enter Total of lines 31 thru 40)
42
SalariesAndWagesGasMaintenanceAbstract
Maintenance
43
SalariesAndWagesGasMaintenanceProductionManufacturedGas
Production - Manufactured Gas
44
SalariesAndWagesGasMaintenanceProductionNaturalGas
Production-Natural Gas (Including Exploration and Development)
45
SalariesAndWagesGasMaintenanceOtherGasSupply
Other Gas Supply
46
SalariesAndWagesGasMaintenanceStorageLngTerminalingAndProcessing
Storage, LNG Terminaling and Processing
47
SalariesAndWagesGasMaintenanceTransmission
Transmission
48
SalariesAndWagesGasMaintenanceDistribution
Distribution
49
SalariesAndWagesGasMaintenanceAdministrativeAndGeneral
Administrative and General
50
SalariesAndWagesGasMaintenance
TOTAL Maint. (Enter Total of lines 43 thru 49)
51
SalariesAndWagesGasOperationAndMaintenanceAbstract
Total Operation and Maintenance
52
SalariesAndWagesGasProductionManufacturedGas
Production-Manufactured Gas (Enter Total of lines 31 and 43)
53
SalariesAndWagesGasProductionNaturalGas
Production-Natural Gas (Including Expl. and Dev.) (Total lines 32,
54
SalariesAndWagesGasOtherGasSupply
Other Gas Supply (Enter Total of lines 33 and 45)
55
SalariesAndWagesGasStorageLngTerminalingAndProcessing
Storage, LNG Terminaling and Processing (Total of lines 31 thru
56
SalariesAndWagesGasTransmission
Transmission (Lines 35 and 47)
57
SalariesAndWagesGasDistribution
Distribution (Lines 36 and 48)
58
SalariesAndWagesGasCustomerAccounts
Customer Accounts (Line 37)
59
SalariesAndWagesGasCustomerServiceAndInformational
Customer Service and Informational (Line 38)
60
SalariesAndWagesGasSales
Sales (Line 39)
61
SalariesAndWagesGasAdministrativeAndGeneral
Administrative and General (Lines 40 and 49)
62
SalariesAndWagesGasOperationAndMaintenance
TOTAL Operation and Maint. (Total of lines 52 thru 61)
63
SalariesAndWagesOtherUtilityDepartmentsAbstract
Other Utility Departments
64
SalariesAndWagesOtherUtilityDepartmentsOperationAndMaintenance
Operation and Maintenance
65
SalariesAndWagesOperationsAndMaintenance
TOTAL All Utility Dept. (Total of lines 28, 62, and 64)
46,109,219
46,109,219
66
SalariesAndWagesUtilityPlantAbstract
Utility Plant
67
SalariesAndWagesUtilityPlantConstructionAbstract
Construction (By Utility Departments)
68
SalariesAndWagesUtilityPlantConstructionElectricPlant
Electric Plant
34,438,047
34,438,047
69
SalariesAndWagesUtilityPlantConstructionGasPlant
Gas Plant
70
SalariesAndWagesUtilityPlantConstructionOther
Other (provide details in footnote):
71
SalariesAndWagesUtilityPlantConstruction
TOTAL Construction (Total of lines 68 thru 70)
34,438,047
34,438,047
72
SalariesAndWagesPlantRemovalAbstract
Plant Removal (By Utility Departments)
73
SalariesAndWagesPlantRemovalElectricPlant
Electric Plant
2,559,154
2,559,154
74
SalariesAndWagesPlantRemovalGasPlant
Gas Plant
75
SalariesAndWagesPlantRemovalOther
Other (provide details in footnote):
76
SalariesAndWagesPlantRemoval
TOTAL Plant Removal (Total of lines 73 thru 75)
2,559,154
2,559,154
77
SalariesAndWagesOtherAccountsAbstract
Other Accounts (Specify, provide details in footnote):
78
SalariesAndWagesOtherAccountsDescription
Other Accounts (Specify, provide details in footnote):
79
SalariesAndWagesOtherAccountsDescription
Fuel Stock Exp Undistributed (Account 152)
80
SalariesAndWagesOtherAccountsDescription
Stores Expense Undistributed (Account 163)
1,829,698
1,829,698
81
SalariesAndWagesOtherAccountsDescription
Miscellaneous Current and Accrued Assets (Account 174)
1,048,091
1,048,091
82
SalariesAndWagesOtherAccountsDescription
Clearing Accounts (Account 184)
2,744,039
2,744,039
83
SalariesAndWagesOtherAccountsDescription
Miscellaneous Deferred Debits (Account 186)
119,606
119,606
84
SalariesAndWagesOtherAccountsDescription
Accumulated Provisions for Property Insurance (Account 2281)
7,538,536
7,538,536
85
SalariesAndWagesOtherAccountsDescription
Accumulated Miscellaneous Operating Provisions (Account 2284)
1,238
1,238
86
SalariesAndWagesOtherAccountsDescription
Civil, Political, and Related Expenses (Account 4264)
772,586
772,586
87
SalariesAndWagesOtherAccountsDescription
Other Deductions (Account 4265)
23,480
23,480
88
SalariesAndWagesOtherAccountsDescription
89
SalariesAndWagesOtherAccountsDescription
90
SalariesAndWagesOtherAccountsDescription
91
SalariesAndWagesOtherAccountsDescription
92
SalariesAndWagesOtherAccountsDescription
93
SalariesAndWagesOtherAccountsDescription
94
SalariesAndWagesOtherAccountsDescription
95
SalariesAndWagesOtherAccounts
TOTAL Other Accounts
11,981,092
11,981,092
96
SalariesAndWagesGeneralExpense
TOTAL SALARIES AND WAGES
95,087,512
(a)
95,087,512


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
FOOTNOTE DATA

(a) Concept: SalariesAndWagesGeneralExpense
The following payroll charges from Entergy Services are not included in this schedule and are included in the Electric O&M schedule (pages 320-323) only:

CHARGES
Production: $5,274,707 
Transmission: $4,377,238 
Distribution: $2,050,249 
Customer Accts: $2,095,628 
Customer Service: $286,604 
Sales: $43,555 
Administrative & General: $21,970,328 

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
COMMON UTILITY PLANT AND EXPENSES
  1. Describe the property carried in the utility's accounts as common utility plant and show the book cost of such plant at end of year classified by accounts as provided by Electric Plant Instruction 13, Common Utility Plant, of the Uniform System of Accounts. Also show the allocation of such plant costs to the respective departments using the common utility plant and explain the basis of allocation used, giving the allocation factors.
  2. Furnish the accumulated provisions for depreciation and amortization at end of year, showing the amounts and classifications of such accumulated provisions, and amounts allocated to utility departments using the common utility plant to which such accumulated provisions relate, including explanation of basis of allocation and factors used.
  3. Give for the year the expenses of operation, maintenance, rents, depreciation, and amortization for common utility plant classified by accounts as provided by the Uniform System of Accounts. Show the allocation of such expenses to the departments using the common utility plant to which such expenses are related. Explain the basis of allocation used and give the factors of allocation.
  4. Give date of approval by the Commission for use of the common utility plant classification and reference to the order of the Commission or other authorization.


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
AMOUNTS INCLUDED IN ISO/RTO SETTLEMENT STATEMENTS
  1. The respondent shall report below the details called for concerning amounts it recorded in Account 555, Purchase Power, and Account 447, Sales for Resale, for items shown on ISO/RTO Settlement Statements. Transactions should be separately netted for each ISO/RTO administered energy market for purposes of determining whether an entity is a net seller or purchaser in a given hour. Net megawatt hours are to be used as the basis for determining whether a net purchase or sale has occurred. In each monthly reporting period, the hourly sale and purchase net amounts are to be aggregated and separately reported in Account 447, Sales for Resale, or Account 555, Purchased Power, respectively.
Line No.
Description of Item(s)
(a)
Balance at End of Quarter 1
(b)
Balance at End of Quarter 2
(c)
Balance at End of Quarter 3
(d)
Balance at End of Year
(e)
1 Energy
2 Net Purchases (Account 555)
17,817,170
26,920,896
41,781,359
74,121,232
2.1 Net Purchases (Account 555.1)
3 Net Sales (Account 447)
38,903,198
82,225,655
117,275,176
122,203,045
4 Transmission Rights
5 Ancillary Services
6 Other Items (list separately)
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46 TOTAL
21,086,028
55,304,759
75,493,817
48,081,813


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
PURCHASES AND SALES OF ANCILLARY SERVICES
Report the amounts for each type of ancillary service shown in column (a) for the year as specified in Order No. 888 and defined in the respondents Open Access Transmission Tariff.
In columns for usage, report usage-related billing determinant and the unit of measure.
  1. On Line 1 columns (b), (c), (d), and (e) report the amount of ancillary services purchased and sold during the year.
  2. On Line 2 columns (b), (c), (d), and (e) report the amount of reactive supply and voltage control services purchased and sold during the year.
  3. On Line 3 columns (b), (c), (d), and (e) report the amount of regulation and frequency response services purchased and sold during the year.
  4. On Line 4 columns (b), (c), (d), and (e) report the amount of energy imbalance services purchased and sold during the year.
  5. On Lines 5 and 6, columns (b), (c), (d), and (e) report the amount of operating reserve spinning and supplement services purchased and sold during the period.
  6. On Line 7 columns (b), (c), (d), and (e) report the total amount of all other types ancillary services purchased or sold during the year. Include in a footnote and specify the amount for each type of other ancillary service provided.
Amount Purchased for the Year Amount Sold for the Year
Usage - Related Billing Determinant Usage - Related Billing Determinant
Line No.
Type of Ancillary Service
(a)
Number of Units
(b)
Unit of Measure
(c)
Dollar
(d)
Number of Units
(e)
Unit of Measure
(f)
Dollars
(g)
1
Scheduling, System Control and Dispatch
627,022
2
Reactive Supply and Voltage
7,299,681
9,521,697
3
Regulation and Frequency Response
4
Energy Imbalance
5
Operating Reserve - Spinning
6
Operating Reserve - Supplement
7
Other
8
Total (Lines 1 thru 7)
7,299,681
(a)
10,148,719


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
FOOTNOTE DATA

(a) Concept: AncillaryServicesSoldAmount
Entergy Mississippi is a transmission owning member of Midwest Independent Transmission System Operator (MISO) RTO. Entergy Mississippi does not purchase or sell transmission services or ancillary services directly. Instead, Entergy Mississippi receives revenues and incurs expenses from transmission services and ancillary sold by MISO. MISO distributes the revenue that it receives to the transmission owner and the transmission owner pays MISO for the related expenses incurred.

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
MONTHLY TRANSMISSION SYSTEM PEAK LOAD
  1. Report the monthly peak load on the respondent's transmission system. If the respondent has two or more power systems which are not physically integrated, furnish the required information for each non-integrated system.
  2. Report on Column (b) by month the transmission system's peak load.
  3. Report on Columns (c ) and (d) the specified information for each monthly transmission - system peak load reported on Column (b).
  4. Report on Columns (e) through (j) by month the system' monthly maximum megawatt load by statistical classifications. See General Instruction for the definition of each statistical classification.
Line No.
Month
(a)
Monthly Peak MW - Total
(b)
Day of Monthly Peak
(c)
Hour of Monthly Peak
(d)
Firm Network Service for Self
(e)
Firm Network Service for Others
(f)
Long-Term Firm Point-to-point Reservations
(g)
Other Long-Term Firm Service
(h)
Short-Term Firm Point-to-point Reservation
(i)
Other Service
(j)
NAME OF SYSTEM: Entergy Mississippi, LLC
1
January
2,665
11
20
2,022
643
2
February
3,033
15
20
2,266
767
3
March
2,201
2
20
1,665
536
4
Total for Quarter 1
5,953
1,946
0
0
0
0
5
April
2,506
28
16
2,004
502
6
May
2,957
27
17
2,312
645
7
June
3,323
15
16
2,608
715
8
Total for Quarter 2
6,924
1,862
0
0
0
0
9
July
3,632
29
16
2,811
821
10
August
3,618
10
17
2,774
844
11
September
3,331
1
16
2,631
700
12
Total for Quarter 3
8,216
2,365
0
0
0
0
13
October
2,748
15
16
2,135
613
14
November
2,113
29
9
1,592
521
15
December
2,214
22
9
1,660
554
16
Total for Quarter 4
5,387
1,688
0
0
0
0
17
Total
26,480
7,861
0
0
0
0


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
Monthly ISO/RTO Transmission System Peak Load
  1. Report the monthly peak load on the respondent's transmission system. If the Respondent has two or more power systems which are not physically integrated, furnish the required information for each non-integrated system.
  2. Report on Column (b) by month the transmission system's peak load.
  3. Report on Column (c) and (d) the specified information for each monthly transmission - system peak load reported on Column (b).
  4. Report on Columns (e) through (i) by month the system’s transmission usage by classification. Amounts reported as Through and Out Service in Column (g) are to be excluded from those amounts reported in Columns (e) and (f).
  5. Amounts reported in Column (j) for Total Usage is the sum of Columns (h) and (i).
Line No.
Month
(a)
Monthly Peak MW - Total
(b)
Day of Monthly Peak
(c)
Hour of Monthly Peak
(d)
Import into ISO/RTO
(e)
Exports from ISO/RTO
(f)
Through and Out Service
(g)
Network Service Usage
(h)
Point-to-Point Service Usage
(i)
Total Usage
(j)
NAME OF SYSTEM: 0
1
January
0
2
February
0
3
March
0
4
Total for Quarter 1
0
0
0
0
0
0
5
April
0
6
May
0
7
June
0
8
Total for Quarter 2
0
0
0
0
0
0
9
July
0
10
August
0
11
September
0
12
Total for Quarter 3
0
0
0
0
0
0
13
October
0
14
November
0
15
December
0
16
Total for Quarter 4
0
0
0
0
0
0
17
Total Year to Date/Year
0
0
0
0
0
0


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

2022-04-15
Year/Period of Report

End of:
2021
/
Q4
ELECTRIC ENERGY ACCOUNT

Report below the information called for concerning the disposition of electric energy generated, purchased, exchanged and wheeled during the year.

Line No. Item
(a)
MegaWatt Hours
(b)
Line No. Item
(a)
MegaWatt Hours
(b)
1
SOURCES OF ENERGY
21
DISPOSITION OF ENERGY
2
Generation (Excluding Station Use):
22
Sales to Ultimate Consumers (Including Interdepartmental Sales)
12,744,935
3
Steam
11,821,870
23
Requirements Sales for Resale (See instruction 4, page 311.)
4
Nuclear
24
Non-Requirements Sales for Resale (See instruction 4, page 311.)
4,363,569
5
Hydro-Conventional
25
Energy Furnished Without Charge
6
Hydro-Pumped Storage
26
Energy Used by the Company (Electric Dept Only, Excluding Station Use)
11,020
7
Other
1,406
27
Total Energy Losses
629,099
8
Less Energy for Pumping
27.1
Total Energy Stored
9
Net Generation (Enter Total of lines 3 through 8)
11,823,276
28
TOTAL (Enter Total of Lines 22 Through 27.1) MUST EQUAL LINE 20 UNDER SOURCES
17,748,623
10
Purchases (other than for Energy Storage)
5,925,347
10.1
Purchases for Energy Storage
0
11
Power Exchanges:
12
Received
0
13
Delivered
0
14
Net Exchanges (Line 12 minus line 13)
0
15
Transmission For Other (Wheeling)
16
Received
17
Delivered
18
Net Transmission for Other (Line 16 minus line 17)
0
19
Transmission By Others Losses
20
TOTAL (Enter Total of Lines 9, 10, 10.1, 14, 18 and 19)
17,748,623


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
MONTHLY PEAKS AND OUTPUT
  1. Report the monthly peak load and energy output. If the respondent has two or more power which are not physically integrated, furnish the required information for each non- integrated system.
  2. Report in column (b) by month the system’s output in Megawatt hours for each month.
  3. Report in column (c) by month the non-requirements sales for resale. Include in the monthly amounts any energy losses associated with the sales.
  4. Report in column (d) by month the system’s monthly maximum megawatt load (60 minute integration) associated with the system.
  5. Report in column (e) and (f) the specified information for each monthly peak load reported in column (d).
Line No.
MonthAxis
Month
(a)
EnergyActivity
Total Monthly Energy
(b)
NonRequiredSalesForResaleEnergy
Monthly Non-Requirement Sales for Resale & Associated Losses
(c)
MonthlyPeakLoad
Monthly Peak - Megawatts
(d)
DayOfMonthlyPeak
Monthly Peak - Day of Month
(e)
HourOfMonthlyPeak
Monthly Peak - Hour
(f)
NAME OF SYSTEM: Entergy Mississippi, LLC
29
January
1,755,829
645,152
2,113
11
20
30
February
1,661,647
584,475
2,332
15
20
31
March
1,181,501
222,627
1,779
3
9
32
April
1,154,185
239,880
1,963
28
16
33
May
1,995,681
958,726
2,416
27
17
34
June
1,720,008
444,790
2,692
14
17
35
July
1,808,394
413,875
2,884
29
16
36
August
1,820,636
374,883
2,854
23
17
37
September
1,533,011
345,362
2,718
1
16
38
October
1,087,671
32,452
2,220
15
16
39
November
968,120
16,643
1,683
29
9
40
December
1,061,940
84,704
1,758
13
9
41
Total
17,748,623
4,363,569


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
Steam Electric Generating Plant Statistics

1. Report data for plant in Service only.
2. Large plants are steam plants with installed capacity (name plate rating) of 25,000 Kw or more. Report in this page gas-turbine and internal combustion plants of 10,000 Kw or more, and nuclear plants.
3. Indicate by a footnote any plant leased or operated as a joint facility.
4. If net peak demand for 60 minutes is not available, give data which is available, specifying period.
5. If any employees attend more than one plant, report on line 11 the approximate average number of employees assignable to each plant.
6. If gas is used and purchased on a therm basis report the Btu content or the gas and the quantity of fuel burned converted to Mct.
7. Quantities of fuel burned (Line 38) and average cost per unit of fuel burned (Line 41) must be consistent with charges to expense accounts 501 and 547 (Line 42) as show on Line 20.
8. If more than one fuel is burned in a plant furnish only the composite heat rate for all fuels burned.
9. Items under Cost of Plant are based on USofA accounts. Production expenses do not include Purchased Power, System Control and Load Dispatching, and Other Expenses Classified as Other Power Supply Expenses.
10. For IC and GT plants, report Operating Expenses, Account Nos. 547 and 549 on Line 25 "Electric Expenses," and Maintenance Account Nos. 553 and 554 on Line 32, "Maintenance of Electric Plant." Indicate plants designed for peak load service. Designate automatically operated plants.
11. For a plant equipped with combinations of fossil fuel steam, nuclear steam, hydro, internal combustion or gas-turbine equipment, report each as a separate plant. However, if a gas-turbine unit functions in a combined cycle operation with a conventional steam unit, include the gas-turbine with the steam plant.
12. If a nuclear power generating plant, briefly explain by footnote (a) accounting method for cost of power generated including any excess costs attributed to research and development; (b) types of cost units used for the various components of fuel cost; and (c) any other informative data concerning plant type fuel used, fuel enrichment type and quantity for the report period and other physical and operating characteristics of plant.

Line No.
Item
(a)
Plant Name:
Attala
Plant Name:
Baxter Wilson
Plant Name:
Choctaw
Plant Name:
Gerald Andrus
Plant Name:
Hinds
Plant Name:
(a)
Independence
1
PlantKind
Kind of Plant (Internal Comb, Gas Turb, Nuclear)
Gas Turbine
Steam
Combined Cycle
Steam
Gas Turbine
Steam
2
PlantConstructionType
Type of Constr (Conventional, Outdoor, Boiler, etc)
Outdoor Boiler
Outdoor
Outdoor Boiler
Outdoor Boiler
3
YearPlantOriginallyConstructed
Year Originally Constructed
2001
1966
2019
1975
2001
1983
4
YearLastUnitOfPlantInstalled
Year Last Unit was Installed
2001
1971
2019
1975
2001
1984
5
InstalledCapacityOfPlant
Total Installed Cap (Max Gen Name Plate Ratings-MW)
551
545
899
781
600
1,800
6
NetPeakDemandOnPlant
Net Peak Demand on Plant - MW (60 minutes)
525
513
934
727
553
1,683
7
PlantHoursConnectedToLoad
Plant Hours Connected to Load
5,831
2,365
5,429
580
7,920
7,632
8
NetContinuousPlantCapability
Net Continuous Plant Capability (Megawatts)
0
0
0
0
0
0
9
NetContinuousPlantCapabilityNotLimitedByCondenserWater
When Not Limited by Condenser Water
501
559
848
750
526
1,681
10
NetContinuousPlantCapabilityLimitedByCondenserWater
When Limited by Condenser Water
459
494
787
728
482
1,664
11
PlantAverageNumberOfEmployees
Average Number of Employees
30
28
30
32
35
51
12
NetGenerationExcludingPlantUse
Net Generation, Exclusive of Plant Use - kWh
2,492,536,672
751,159,844
3,885,800,485
175,101,000
3,488,764,194
1,028,507,943
13
CostOfLandAndLandRightsSteamProduction
Cost of Plant: Land and Land Rights
128,931
359,115
2,761,498
331,301
1,362,657
1,068,160
14
CostOfStructuresAndImprovementsSteamProduction
Structures and Improvements
16,743,407
12,877,536
208,521,282
30,958,749
100,949,699
22,316,303
15
CostOfEquipmentSteamProduction
Equipment Costs
120,250,937
86,426,450
291,858,881
171,920,396
230,911,378
256,136,802
16
AssetRetirementCostsSteamProduction
Asset Retirement Costs
0
136,135
0
0
1,507,847
17
CostOfPlant
Total cost (total 13 thru 20)
137,123,275
99,799,236
503,141,661
203,210,446
333,223,734
281,029,112
18
CostPerKilowattOfInstalledCapacity
Cost per KW of Installed Capacity (line 17/5) Including
249
183
560
260
555
156
19
OperationSupervisionAndEngineeringExpense
Production Expenses: Oper, Supv, & Engr
1,027,157
751,249
469,544
2,108,940
534,657
647,876
20
FuelSteamPowerGeneration
Fuel
66,170,198
31,857,250
109,062,385
11,006,127
95,086,745
26,347,662
21
CoolantsAndWater
Coolants and Water (Nuclear Plants Only)
0
0
0
22
SteamExpensesSteamPowerGeneration
Steam Expenses
3,620
825,224
6,126
1,200,616
3,800
239,608
23
SteamFromOtherSources
Steam From Other Sources
0
0
24
SteamTransferredCredit
Steam Transferred (Cr)
0
0
25
ElectricExpensesSteamPowerGeneration
Electric Expenses
602,457
375,003
6,458
22,294
215,237
191,524
26
MiscellaneousSteamPowerExpenses
Misc Steam (or Nuclear) Power Expenses
4,871,032
2,304,607
1,048,700
2,411,736
5,093,355
1,397,324
27
RentsSteamPowerGeneration
Rents
81,048
4,984
4,577
27,136
5,540
268
28
Allowances
Allowances
953
12,780
1,432
1,552
995
8,672
29
MaintenanceSupervisionAndEngineeringSteamPowerGeneration
Maintenance Supervision and Engineering
64,662
33,005
49,296
312,387
32,167
46,191
30
MaintenanceOfStructuresSteamPowerGeneration
Maintenance of Structures
146,331
153,941
609
380,544
196,403
209,772
31
MaintenanceOfBoilerPlantSteamPowerGeneration
Maintenance of Boiler (or reactor) Plant
6,516
1,297,075
11,030
3,816,465
6,842
2,828,018
32
MaintenanceOfElectricPlantSteamPowerGeneration
Maintenance of Electric Plant
3,023,821
353,605
111
1,696,877
2,766,469
1,467,125
33
MaintenanceOfMiscellaneousSteamPlant
Maintenance of Misc Steam (or Nuclear) Plant
269,815
348,093
15,899,786
493,532
575,657
2,069,475
34
PowerProductionExpensesSteamPower
Total Production Expenses
76,267,610
38,316,816
126,550,900
23,478,206
104,517,867
35,452,979
35
ExpensesPerNetKilowattHour
Expenses per Net kWh
0.0306
0.0510
0.0326
0.1341
0.0300
0.0345
35
FuelKindAxis
Plant Name
Attala
Baxter Wilson
Baxter Wilson
Choctaw
Gerald Andrus
Gerald Andrus
Hinds
Independence
Independence
36
FuelKind
Fuel Kind
Gas
Gas
Oil
Gas
Gas
Oil
Gas
Coal
Oil
37
FuelUnit
Fuel Unit
Mcf
Mcf
bbl
Mcf
Mcf
bbl
Mcf
T
bbl
38
QuantityOfFuelBurned
Quantity (Units) of Fuel Burned
16,533,487
7,247,537
1,319
25,091,773
1,911,821
298
23,235,161
62,515
5,962
39
FuelBurnedAverageHeatContent
Avg Heat Cont - Fuel Burned (btu/indicate if nuclear)
1,060,039
1,093,851
140,476
1,078,744
1,053,902
140,476
1,062,495
85,603
140,476
40
AverageCostOfFuelPerUnitAsDelivered
Avg Cost of Fuel/unit, as Delvd f.o.b. during year
41
AverageCostOfFuelPerUnitBurned
Average Cost of Fuel per Unit Burned
4
4
165
4
5
1,410
4
414
82
42
AverageCostOfFuelBurnedPerMillionBritishThermalUnit
Average Cost of Fuel Burned per Million BTU
4
4
28
4
5
239
4
2
14
43
AverageCostOfFuelBurnedPerKilowattHourNetGeneration
Average Cost of Fuel Burned per kWh Net Gen
44
AverageBritishThermalUnitPerKilowattHourNetGeneration
Average BTU per kWh Net Generation
7,046
10,718
6,969
12,578
7,080
10,514


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
FOOTNOTE DATA

(a) Concept: PlantName
Indepedence - Reflects Entergy Mississippi's 25% ownership interest in Independence Units 1 and 2.

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
Hydroelectric Generating Plant Statistics
  1. Large plants are hydro plants of 10,000 Kw or more of installed capacity (name plate ratings).
  2. If any plant is leased, operated under a license from the Federal Energy Regulatory Commission, or operated as a joint facility, indicate such facts in a footnote. If licensed project, give project number.
  3. If net peak demand for 60 minutes is not available, give that which is available specifying period.
  4. If a group of employees attends more than one generating plant, report on line 11 the approximate average number of employees assignable to each plant.
  5. The items under Cost of Plant represent accounts or combinations of accounts prescribed by the Uniform System of Accounts. Production Expenses do not include Purchased Power, System control and Load Dispatching, and Other Expenses classified as "Other Power Supply Expenses."
  6. Report as a separate plant any plant equipped with combinations of steam, hydro, internal combustion engine, or gas turbine equipment.
Line No.
Item
(a)
FERC Licensed Project No.
0
Plant Name:
0
1
PlantKind
Kind of Plant (Run-of-River or Storage)
2
PlantConstructionType
Plant Construction type (Conventional or Outdoor)
3
YearPlantOriginallyConstructed
Year Originally Constructed
4
YearLastUnitOfPlantInstalled
Year Last Unit was Installed
5
InstalledCapacityOfPlant
Total installed cap (Gen name plate Rating in MW)
6
NetPeakDemandOnPlant
Net Peak Demand on Plant-Megawatts (60 minutes)
7
PlantHoursConnectedToLoad
Plant Hours Connect to Load
8
NetPlantCapabilityAbstract
Net Plant Capability (in megawatts)
9
NetPlantCapabilityUnderMostFavorableOperatingConditions
(a) Under Most Favorable Oper Conditions
10
NetPlantCapabilityUnderMostAdverseOperatingConditions
(b) Under the Most Adverse Oper Conditions
11
PlantAverageNumberOfEmployees
Average Number of Employees
12
NetGenerationExcludingPlantUse
Net Generation, Exclusive of Plant Use - kWh
13
CostOfPlantAbstract
Cost of Plant
14
CostOfLandAndLandRightsHydroelectricProduction
Land and Land Rights
15
CostOfStructuresAndImprovementsHydroelectricProduction
Structures and Improvements
16
CostOfReservoirsDamsAndWaterwaysHydroelectricProduction
Reservoirs, Dams, and Waterways
17
EquipmentCostsHydroelectricProduction
Equipment Costs
18
CostOfRoadsRailroadsAndBridgesHydroelectricProduction
Roads, Railroads, and Bridges
19
AssetRetirementCostsHydroelectricProduction
Asset Retirement Costs
20
CostOfPlant
Total cost (total 13 thru 20)
21
CostPerKilowattOfInstalledCapacity
Cost per KW of Installed Capacity (line 20 / 5)
22
ProductionExpensesAbstract
Production Expenses
23
OperationSupervisionAndEngineeringExpense
Operation Supervision and Engineering
24
WaterForPower
Water for Power
25
HydraulicExpenses
Hydraulic Expenses
26
ElectricExpensesHydraulicPowerGeneration
Electric Expenses
27
MiscellaneousHydraulicPowerGenerationExpenses
Misc Hydraulic Power Generation Expenses
28
RentsHydraulicPowerGeneration
Rents
29
MaintenanceSupervisionAndEngineeringHydraulicPowerGeneration
Maintenance Supervision and Engineering
30
MaintenanceOfStructuresHydraulicPowerGeneration
Maintenance of Structures
31
MaintenanceOfReservoirsDamsAndWaterways
Maintenance of Reservoirs, Dams, and Waterways
32
MaintenanceOfElectricPlantHydraulicPowerGeneration
Maintenance of Electric Plant
33
MaintenanceOfMiscellaneousHydraulicPlant
Maintenance of Misc Hydraulic Plant
34
PowerProductionExpensesHydraulicPower
Total Production Expenses (total 23 thru 33)
35
ExpensesPerNetKilowattHour
Expenses per net kWh


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
Pumped Storage Generating Plant Statistics
  1. Large plants and pumped storage plants of 10,000 Kw or more of installed capacity (name plate ratings).
  2. If any plant is leased, operating under a license from the Federal Energy Regulatory Commission, or operated as a joint facility, indicate such facts in a footnote. Give project number.
  3. If net peak demand for 60 minutes is not available, give that which is available, specifying period.
  4. If a group of employees attends more than one generating plant, report on Line 8 the approximate average number of employees assignable to each plant.
  5. The items under Cost of Plant represent accounts or combinations of accounts prescribed by the Uniform System of Accounts. Production Expenses do not include Purchased Power System Control and Load Dispatching, and Other Expenses classified as "Other Power Supply Expenses."
  6. Pumping energy (Line 10) is that energy measured as input to the plant for pumping purposes.
  7. Include on Line 36 the cost of energy used in pumping into the storage reservoir. When this item cannot be accurately computed leave Lines 36, 37 and 38 blank and describe at the bottom of the schedule the company's principal sources of pumping power, the estimated amounts of energy from each station or other source that individually provides more than 10 percent of the total energy used for pumping, and production expenses per net MWH as reported herein for each source described. Group together stations and other resources which individually provide less than 10 percent of total pumping energy. If contracts are made with others to purchase power for pumping, give the supplier contract number, and date of contract.
Line No.
Item
(a)
FERC Licensed Project No.
0
Plant Name:
0
1
PlantConstructionType
Type of Plant Construction (Conventional or Outdoor)
2
YearPlantOriginallyConstructed
Year Originally Constructed
3
YearLastUnitOfPlantInstalled
Year Last Unit was Installed
4
InstalledCapacityOfPlant
Total installed cap (Gen name plate Rating in MW)
5
NetPeakDemandOnPlant
Net Peak Demaind on Plant-Megawatts (60 minutes)
6
PlantHoursConnectedToLoad
Plant Hours Connect to Load While Generating
7
NetContinuousPlantCapability
Net Plant Capability (in megawatts)
8
PlantAverageNumberOfEmployees
Average Number of Employees
9
NetGenerationExcludingPlantUse
Generation, Exclusive of Plant Use - kWh
10
EnergyUsedForPumping
Energy Used for Pumping
11
NetOutputForLoad
Net Output for Load (line 9 - line 10) - Kwh
0
12
CostOfPlantAbstract
Cost of Plant
13
CostOfLandAndLandRightsPumpedStoragePlant
Land and Land Rights
14
CostOfStructuresAndImprovementsPumpedStoragePlant
Structures and Improvements
15
CostOfReservoirsDamsAndWaterwaysPumpedStoragePlant
Reservoirs, Dams, and Waterways
16
CostOfWaterWheelsTurbinesAndGeneratorsPumpedStoragePlant
Water Wheels, Turbines, and Generators
17
CostOfAccessoryElectricEquipmentPumpedStoragePlant
Accessory Electric Equipment
18
CostOfMiscellaneousPowerPlantEquipmentPumpedStoragePlant
Miscellaneous Powerplant Equipment
19
CostOfRoadsRailroadsAndBridgesPumpedStoragePlant
Roads, Railroads, and Bridges
20
AssetRetirementCostsPumpedStoragePlant
Asset Retirement Costs
21
CostOfPlant
Total cost (total 13 thru 20)
22
CostPerKilowattOfInstalledCapacity
Cost per KW of installed cap (line 21 / 4)
23
ProductionExpensesAbstract
Production Expenses
24
OperationSupervisionAndEngineeringExpense
Operation Supervision and Engineering
25
WaterForPower
Water for Power
26
PumpedStorageExpenses
Pumped Storage Expenses
27
ElectricExpensesPumpedStoragePlant
Electric Expenses
28
MiscellaneousPumpedStoragePowerGenerationExpenses
Misc Pumped Storage Power generation Expenses
29
RentsPumpedStoragePlant
Rents
30
MaintenanceSupervisionAndEngineeringPumpedStoragePlant
Maintenance Supervision and Engineering
31
MaintenanceOfStructuresPumpedStoragePlant
Maintenance of Structures
32
MaintenanceOfReservoirsDamsAndWaterwaysPumpedStoragePlant
Maintenance of Reservoirs, Dams, and Waterways
33
MaintenanceOfElectricPlantPumpedStoragePlant
Maintenance of Electric Plant
34
MaintenanceOfMiscellaneousPumpedStoragePlant
Maintenance of Misc Pumped Storage Plant
35
PowerProductionExpenseBeforePumpingExpenses
Production Exp Before Pumping Exp (24 thru 34)
36
PumpingExpenses
Pumping Expenses
37
PowerProductionExpensesPumpedStoragePlant
Total Production Exp (total 35 and 36)
38
ExpensesPerNetKilowattHour
Expenses per kWh (line 37 / 9)
39
ExpensesPerNetKilowattHourGenerationAndPumping
Expenses per KWh of Generation and Pumping (line 37/(line 9 + line 10))
0


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
GENERATING PLANT STATISTICS (Small Plants)
  1. Small generating plants are steam plants of, less than 25,000 Kw; internal combustion and gas turbine-plants, conventional hydro plants and pumped storage plants of less than 10,000 Kw installed capacity (name plate rating).
  2. Designate any plant leased from others, operated under a license from the Federal Energy Regulatory Commission, or operated as a joint facility, and give a concise statement of the facts in a footnote. If licensed project, give project number in footnote.
  3. List plants appropriately under subheadings for steam, hydro, nuclear, internal combustion and gas turbine plants. For nuclear, see instruction 11, Page 402.
  4. If net peak demand for 60 minutes is not available, give the which is available, specifying period.
  5. If any plant is equipped with combinations of steam, hydro internal combustion or gas turbine equipment, report each as a separate plant. However, if the exhaust heat from the gas turbine is utilized in a steam turbine regenerative feed water cycle, or for preheated combustion air in a boiler, report as one plant.
Production Expenses
Line No.
PlantName
Name of Plant
(a)
YearPlantOriginallyConstructed
Year Orig. Const.
(b)
InstalledCapacityOfPlant
Installed Capacity Name Plate Rating (MW)
(c)
NetPeakDemandOnPlant
Net Peak Demand MW (60 min)
(d)
NetGenerationExcludingPlantUse
Net Generation Excluding Plant Use
(e)
CostOfPlant
Cost of Plant
(f)
PlantCostPerMw
Plant Cost (Incl Asset Retire. Costs) Per MW
(g)
OperatingExpensesExcludingFuel
Operation Exc'l. Fuel
(h)
FuelProductionExpenses
Fuel Production Expenses
(i)
MaintenanceProductionExpenses
Maintenance Production Expenses
(j)
FuelKind
Kind of Fuel
(k)
FuelCostPerMmbtus
Fuel Costs (in cents (per Million Btu)
(l)
GenerationType
Generation Type
(m)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
ENERGY STORAGE OPERATIONS (Large Plants)
  1. Large Plants are plants of 10,000 Kw or more.
  2. In columns (a) (b) and (c) report the name of the energy storage project, functional classification (Production, Transmission, Distribution), and location.
  3. In column (d), report Megawatt hours (MWH) purchased, generated, or received in exchange transactions for storage.
  4. In columns (e), (f) and (g) report MWHs delivered to the grid to support production, transmission and distribution. The amount reported in column (d) should include MWHs delivered/provided to a generator’s own load requirements or used for the provision of ancillary services.
  5. In columns (h), (i), and (j) report MWHs lost during conversion, storage and discharge of energy.
  6. In column (k) report the MWHs sold.
  7. In column (l), report revenues from energy storage operations. In a footnote, disclose the revenue accounts and revenue amounts related to the income generating activity.
  8. In column (m), report the cost of power purchased for storage operations and reported in Account 555.1, Power Purchased for Storage Operations. If power was purchased from an affiliated seller specify how the cost of the power was determined. In columns (n) and (o), report fuel costs for storage operations associated with self-generated power included in Account 501 and other costs associated with self-generated power.
  9. In columns (q), (r) and (s) report the total project plant costs including but not exclusive of land and land rights, structures and improvements, energy storage equipment, turbines, compressors, generators, switching and conversion equipment, lines and equipment whose primary purpose is to integrate or tie energy storage assets into the power grid, and any other costs associated with the energy storage project included in the property accounts listed.
Line No.
Name of the Energy Storage Project
(a)
Functional Classification
(b)
Location of the Project
(c)
MWHs
(d)
MWHs delivered to the grid to support Production
(e)
MWHs delivered to the grid to support Transmission
(f)
MWHs delivered to the grid to support Distribution
(g)
MWHs Lost During Conversion, Storage and Discharge of Energy Production
(h)
MWHs Lost During Conversion, Storage and Discharge of Energy Transmission
(i)
MWHs Lost During Conversion, Storage and Discharge of Energy Distribution
(j)
MWHs Sold
(k)
Revenues from Energy Storage Operations
(l)
Power Purchased for Storage Operations (555.1) (Dollars)
(m)
Fuel Costs from associated fuel accounts for Storage Operations Associated with Self- Generated Power (Dollars)
(n)
Other Costs Associated with Self-Generated Power (Dollars)
(o)
Project Costs included in
(p)
Production (Dollars)
(q)
Transmission (Dollars)
(r)
Distribution (Dollars)
(s)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
TRANSMISSION LINE STATISTICS
  1. Report information concerning transmission lines, cost of lines, and expenses for year. List each transmission line having nominal voltage of 132 kilovolts or greater. Report transmission lines below these voltages in group totals only for each voltage. If required by a State commission to report individual lines for all voltages, do so but do not group totals for each voltage under 132 kilovolts.
  2. Transmission lines include all lines covered by the definition of transmission system plant as given in the Uniform System of Accounts. Do not report substation costs and expenses on this page.
  3. Exclude from this page any transmission lines for which plant costs are included in Account 121, Nonutility Property.
  4. Indicate whether the type of supporting structure reported in column (e) is: (1) single pole wood or steel; (2) H-frame wood, or steel poles; (3) tower; or (4) underground construction If a transmission line has more than one type of supporting structure, indicate the mileage of each type of construction by the use of brackets and extra lines. Minor portions of a transmission line of a different type of construction need not be distinguished from the remainder of the line.
  5. Report in columns (f) and (g) the total pole miles of each transmission line. Show in column (f) the pole miles of line on structures the cost of which is reported for the line designated; conversely, show in column (g) the pole miles of line on structures the cost of which is reported for another line. Report pole miles of line on leased or partly owned structures in column (g). In a footnote, explain the basis of such occupancy and state whether expenses with respect to such structures are included in the expenses reported for the line designated.
  6. Do not report the same transmission line structure twice. Report Lower voltage Lines and higher voltage lines as one line. Designate in a footnote if you do not include Lower voltage lines with higher voltage lines. If two or more transmission line structures support lines of the same voltage, report the pole miles of the primary structure in column (f) and the pole miles of the other line(s) in column (g).
  7. Designate any transmission line or portion thereof for which the respondent is not the sole owner. If such property is leased from another company, give name of lessor, date and terms of Lease, and amount of rent for year. For any transmission line other than a leased line, or portion thereof, for which the respondent is not the sole owner but which the respondent operates or shares in the operation of, furnish a succinct statement explaining the arrangement and giving particulars (details) of such matters as percent ownership by respondent in the line, name of co-owner, basis of sharing expenses of the Line, and how the expenses borne by the respondent are accounted for, and accounts affected. Specify whether lessor, co-owner, or other party is an associated company.
  8. Designate any transmission line leased to another company and give name of Lessee, date and terms of lease, annual rent for year, and how determined. Specify whether lessee is an associated company.
  9. Base the plant cost figures called for in columns (j) to (l) on the book cost at end of year.
DESIGNATION VOLTAGE (KV) - (Indicate where other than 60 cycle, 3 phase) LENGTH (Pole miles) - (In the case of underground lines report circuit miles) COST OF LINE (Include in column (j) Land, Land rights, and clearing right-of-way) EXPENSES, EXCEPT DEPRECIATION AND TAXES
Line No.
TransmissionLineStartPoint
From
TransmissionLineEndPoint
To
OperatingVoltageOfTransmissionLine
Operating
DesignedVoltageOfTransmissionLine
Designated
SupportingStructureOfTransmissionLineType
Type of Supporting Structure
LengthForStandAloneTransmissionLines
On Structure of Line Designated
LengthForTransmissionLinesAggregatedWithOtherStructures
On Structures of Another Line
NumberOfTransmissionCircuits
Number of Circuits
SizeOfConductorAndMaterial
Size of Conductor and Material
CostOfLandAndLandRightsTransmissionLines
Land
ConstructionAndOtherCostsTransmissionLines
Construction Costs
OverallCostOfTransmissionLine
Total Costs
OperatingExpensesOfTransmissionLine
Operation Expenses
MaintenanceExpensesOfTransmissionLine
Maintenance Expenses
RentExpensesOfTransmissionLine
Rents
OverallExpensesOfTransmissionLine
Total Expenses
(a)
(b)
(c)
(d)
(e)
(f)
(g)
(h)
(i)
(j)
(k)
(l)
(m)
(n)
(o)
(p)
1
10,188,214
4,493,764
165,591
14,847,569
2
RAY BRASWELL
MCKNIGHT (MS/LA ST LN) 500KV LN 504,505 (OPCO TIE) [6980]
500
500
96.66
0.00
1
954 ACSR
3
LAKEOVER
RAY BRASWELL 500KV LN 511 [7130]
500
500
22.50
3.35
2
954 ACSR
4
RAY BRASWELL
BWSES 500KV LN 502 [6880]
500
500
35.54
5.44
2
954 ACSR
5
RAY BRASWELL
WEST POINT 500KV LN 508 [6960]
500
500
82.49
0.00
1
954 ACSR
6
FRANKLIN
BOGALUSA (MS/LA ST LN) 500KV LN 510 (OPCO TIE) [5521]
500
500
51.38
0.00
1
954 ACSR
7
GGNS
BWSES 500KV LN 507 [5620]
500
500
21.46
0.00
1
954 ACSR
8
GGNS
FRANKLIN 500KV LN 506 [5640]
500
500
43.46
0.00
1
954 ACSR
9
BWSES
STERLINGTON (MS/LA ST LN) 500KV LN 503 (OPCO TIE) [5200]
500
500
1.46
1.10
2
3070 ACSR
10
CHOCTAW
FRENCH CAMP 500KV LN 514 [5014]
500
500
0.81
0.00
1
954 ACSR
11
CHOCTAW
WOLF CREEK 500KV LN 515 [5015]
500
500
0.11
0.00
1
954 ACSR
12
All 500 kV Lines
500
500
0.00
0.00
0
14,299,755
54,689,875
68,989,630
13
LAKEOVER
LUCKNEY 230KV LN 211 [2311]
230
230
22.80
8.40
2
1272 ACSR
14
LAKEOVER
YANDELL RD 230KV LN 235 [2335]
230
230
18.30
10.16
2
1272 ACSR
15
REX BROWN SES
RAY BRASWELL 230KV LN 205 [7100]
230
230
9.18
0.00
1
1272 ACSR
16
SOUTH JACKSON
RANKIN 230 KV LN 233 [7350]
230
230
17.69
15.30
2
1272 ACSR
17
SOUTH JACKSON
RAY BRASWELL 230KV LN 206 [7370]
230
230
9.45
9.22
2
1272 ACSR
18
SOUTH JACKSON
RAY BRASWELL 230KV LN 217 [7375]
230
230
13.53
10.95
2
1272 ACSR
19
TUNICA
RITCHIE 230KV LN 212 [7490]
230
230
21.36
0.00
1
1272 ACSR
20
LAKEOVER
REX BROWN EAST 230KV LN 219 [6183]
230
230
1.75
1.57
2
1780 ACSR
21
LAKEOVER
REX BROWN WEST 230KV LN 218 [6184]
230
230
1.74
1.56
2
1780 ACSR
22
CANTON
SOUTH CANTON 230KV LN 230 [6185]
230
230
5.42
1.93
2
1272 ACSR
23
HORN LAKE
GETWELL 230KV LN 225 [6186]
230
230
8.56
4.77
2
1272 ACSR
24
LUCKNEY
RANKIN 230KV LN 211 [6298]
230
230
13.47
0.00
1
1272 ACSR
25
BATESVILLE
MOON LAKE 230KV LN 201 [6300]
230
230
33.01
0.00
1
1272 ACSR
26
MOON LAKE
RITCHIE (MS/AR ST LN) 230KV LN 228 (OPCO TIE) [6320]
230
230
6.80
0.00
1
1272 ACSR
27
MCADAMS
INDIANOLA 230KV LN 215 [6410]
230
230
67.53
0.00
1
1272 ACSR
28
MCADAMS
ATTALA 230KV LN 210 D/C [6415]
230
230
1.17
0.00
1
1272 ACSR
29
MCADAMS
PICKENS 230KV LN 209 [6416]
230
230
16.18
0.00
1
1272 ACSR
30
GERALD ANDRUS SES
TINNIN ROAD 230KV LN 204 [6901]
230
230
78.88
0.00
1
1272 ACSR
31
SOUTH CANTON
RAGSDALE 230KV LN 223 & 224 [5271]
230
230
3.08
2.58
2
1272 ACSR
32
FREEPORT
TUNICA 230KV LN 213,238 [5525]
230
230
31.90
0.00
1
1272 ACSR
33
GASES
LAKE VILLAGE BAGBY (MS/AR ST LN) 230KV LN 202 (OPCO TIE) [5540]
230
230
3.59
0.00
1
1272 ACSR
34
GASES
INDIANOLA 230KV LN 203 [5580]
230
230
33.67
8.38
2
1272 ACSR
35
TILLATOBA
BATESVILLE 230KV LN 208 [5840]
230
230
27.22
0.00
1
1272 ACSR
36
HORN LAKE
FREEPORT 230KV LN 216 [5942]
230
230
3.81
0.00
1
1272 ACSR
37
INDIANOLA
TILLATOBA 230KV LN 207 [6020]
230
230
56.36
0.00
1
1272 ACSR
38
CANTON
PICKENS 230KV LN 230 [5270]
230
230
22.56
0.00
1
1272 ACSR
39
CATLETT
TINNIN RD 230KV LN 234 [5112]
230
230
25.29
0.00
1
1272 ACSR
40
GETWELL
TWINKLETOWN 230KV LN 236 [5007]
230
230
20.55
0.00
1
1272 ACSR
41
TILLATOBA
SOUTH GRENADA 230KV LN 237 [2337]
230
230
19.22
15.97
2
1272 ACSR
42
TINNIN RD
NORRELL 230KV LN 239 [2339]
230
230
6.91
0.00
1
1272 ACSR
43
RAY BRASWELL
NORRELL 230KV LN 240 [2340]
230
230
7.36
3.21
2
1272 ACSR
44
LAKEOVER
HINDS BLACKSTART UNIT INTERCONNECT 230KV LN 242 [2342]
230
230
0.70
0.00
1
954 ACSR
45
SOUTH CANTON
YANDELL RD 230KV LN 214 [2314]
230
230
9.59
3.56
2
1272 ACSR
46
YANDELL RD
CATLETT 230KV LN 234 [2334]
230
230
12.40
2.29
2
1272 ACSR
47
All 230 kV Lines
230
230
0.00
0.00
0
56,125,886
171,690,249
227,816,135
48
HORN LAKE
MEMPHIS 161KV LN 149 (TVA TIE) [5960]
161
161
5.86
0.00
1
666 ACSR
49
All 161 kV Lines
161
161
0.00
0.00
0
19,482
387,573
407,055
50
All 115 kV Lines
115
115
2,027.43
121.95
156
63,293,090
588,738,461
652,031,551
36 TOTAL
3,020.19
231.69
219
133,738,213
815,506,158
949,244,371
10,188,214
4,493,764
165,591
14,847,569


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
TRANSMISSION LINES ADDED DURING YEAR
  1. Report below the information called for concerning Transmission lines added or altered during the year. It is not necessary to report minor revisions of lines.
  2. Provide separate subheadings for overhead and under- ground construction and show each transmission line separately. If actual costs of competed construction are not readily available for reporting columns (l) to (o), it is permissible to report in these columns the costs. Designate, however, if estimated amounts are reported. Include costs of Clearing Land and Rights-of-Way, and Roads and Trails, in column (l) with appropriate footnote, and costs of Underground Conduit in column (m).
  3. If design voltage differs from operating voltage, indicate such fact by footnote; also where line is other than 60 cycle, 3 phase, indicate such other characteristic.
LINE DESIGNATION SUPPORTING STRUCTURE CIRCUITS PER STRUCTURE CONDUCTORS LINE COST
Line No.
TransmissionLineStartPoint
From
TransmissionLineEndPoint
To
LengthOfTransmissionLineAdded
Line Length in Miles
SupportingStructureOfTransmissionLineType
Type
AverageNumberOfSupportingStructuresOfTransmissionLinePerMiles
Average Number per Miles
NumberOfTransmissionCircuitsPerStructurePresent
Present
NumberOfTransmissionCircuitsPerStructureUltimate
Ultimate
ConductorSize
Size
ConductorSpecification
Specification
ConductorConfigurationAndSpacing
Configuration and Spacing
OperatingVoltageOfTransmissionLine
Voltage KV (Operating)
CostOfLandAndLandRightsTransmissionLinesAdded
Land and Land Rights
CostOfPolesTowersAndFixturesTransmissionLinesAdded
Poles, Towers and Fixtures
CostOfConductorsAndDevicesTransmissionLinesAdded
Conductors and Devices
Asset Retire. Costs
CostOfTransmissionLinesAdded
Total
SupportingStructureConstructionType
Construction
(a)
(b)
(c)
(d)
(e)
(f)
(g)
(h)
(i)
(j)
(k)
(l)
(m)
(n)
(o)
(p)
(q)
1
CATLETT
SOUTH CANTON 230 KV LN 244 [2392]
3.59
11
1
1
230
230
1,530,390
7,651,948
6,121,559
15,303,897
2
GETWELL
BYHALIA 230KV LN 241 [2341]
5.88
10
1
1
230
230
1,174,199
5,870,996
4,696,797
11,741,992
44
TOTAL
9.47
21
2
2
2,704,589
13,522,944
10,818,356
27,045,889


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
SUBSTATIONS
  1. Report below the information called for concerning substations of the respondent as of the end of the year.
  2. Substations which serve only one industrial or street railway customer should not be listed below.
  3. Substations with capacities of Less than 10 MVA except those serving customers with energy for resale, may be grouped according to functional character, but the number of such substations must be shown.
  4. Indicate in column (b) the functional character of each substation, designating whether transmission or distribution and whether attended or unattended. At the end of the page, summarize according to function the capacities reported for the individual stations in column (f).
  5. Show in columns (I), (j), and (k) special equipment such as rotary converters, rectifiers, condensers, etc. and auxiliary equipment for increasing capacity.
  6. Designate substations or major items of equipment leased from others, jointly owned with others, or operated otherwise than by reason of sole ownership by the respondent. For any substation or equipment operated under lease, give name of lessor, date and period of lease, and annual rent. For any substation or equipment operated other than by reason of sole ownership or lease, give name of co-owner or other party, explain basis of sharing expenses or other accounting between the parties, and state amounts and accounts affected in respondent's books of account. Specify in each case whether lessor, co-owner, or other party is an associated company.
Character of Substation VOLTAGE (In MVa) Conversion Apparatus and Special Equipment
Line No.
SubstationNameAndLocation
Name and Location of Substation
(a)
SubstationCharacterDescription
Transmission or Distribution
(b)
SubstationCharacterAttendedOrUnattended
Attended or Unattended
(b-1)
PrimaryVoltageLevel
Primary Voltage (In MVa)
(c)
SecondaryVoltageLevel
Secondary Voltage (In MVa)
(d)
TertiaryVoltageLevel
Tertiary Voltage (In MVa)
(e)
SubstationInServiceCapacity
Capacity of Substation (In Service) (In MVa)
(f)
NumberOfTransformersInService
Number of Transformers In Service
(g)
Number of Spare Transformers
(h)
ConversionApparatusAndSpecialEquipmentType
Type of Equipment
(i)
NumberOfConversionApparatusAndSpecialEquipmentUnits
Number of Units
(j)
CapacityOfConversionApparatusAndSpecialEquipment
Total Capacity (In MVa)
(k)
1
AIRPORT/JACKSON
Distribution
Unattended
(a)
115.00
(b)
14.49
56
2
2
ATTALA
Distribution
Unattended
115.00
13.80
20
1
3
BELZONI
Distribution
Unattended
115.00
13.86
45
2
4
BOLTON
Distribution
Unattended
115.00
13.86
19
2
5
BOVINA
Distribution
Unattended
115.00
12.47
11
1
6
BOZEMAN ROAD
Distribution
Unattended
230.00
13.80
73
2
7
BRANDON
Distribution
Unattended
115.00
14.40
89
3
8
BRICKYARD
Distribution
Unattended
115.00
14.40
33
1
9
BROOKHAVEN
Distribution
Unattended
115.00
14.40
81
3
10
BROOKHAVEN/SOUTH
Distribution
Unattended
115.00
14.40
61
2
11
BYHALIA
Distribution
Unattended
230.00
13.80
40
1
12
BYRAM
Distribution
Unattended
115.00
14.49
67
2
13
CANTON
Distribution
Unattended
230.00
13.86
67
2
14
CANTON ROAD/JACKSON
Distribution
Unattended
115.00
14.49
67
2
15
CANTON/SOUTH
Distribution
Unattended
230.00
13.80
73
2
16
CARTHAGE (MS)
Distribution
Unattended
115.00
13.86
45
2
17
CATLETT
Distribution
Unattended
230.00
12.47
80
2
18
CENTREVILLE
Distribution
Unattended
115.00
13.86
40
2
19
CHARITY CHURCH/JACKSON
Distribution
Unattended
230.00
14.40
67
2
20
CHARLESTON
Distribution
Unattended
115.00
14.40
56
2
21
CHURCH ROAD
Distribution
Unattended
230.00
14.40
40
1
22
CLARKSDALE
Distribution
Unattended
115.00
13.86
42
2
23
CLEVELAND [MS]
Distribution
Unattended
115.00
13.86
84
3
24
CLEVELAND/SOUTH
Distribution
Unattended
115.00
13.86
56
2
25
CLINTON [MS]
Distribution
Unattended
115.00
14.49
78
3
26
CLINTON INDUSTRIAL
Distribution
Unattended
230.00
14.49
61
2
27
COLDWATER
Distribution
Unattended
115.00
13.80
67
2
28
COMO
Distribution
Unattended
115.00
13.86
20
2
29
COUNTRY CLUB/JACKSON
Distribution
Unattended
115.00
14.40
61
2
30
CRENSHAW
Distribution
Unattended
115.00
13.86
22
1
31
CRYSTAL SPRINGS
Distribution
Unattended
115.00
13.86
45
2
32
DESOTO
Distribution
Unattended
115.00
14.49
56
2
33
DREW [MS]
Distribution
Unattended
115.00
13.86
35
2
34
DURANT
Distribution
Unattended
115.00
14.49
32
2
35
EDWARDS
Distribution
Unattended
115.00
13.80
32
2
36
ELLIOTT
Distribution
Unattended
115.00
14.40
56
2
37
ELTON RD
Distribution
Unattended
115.00
13.86
20
1
38
ENID
Distribution
Unattended
230.00
14.40
20
1
39
FANNIN ROAD
Distribution
Unattended
115.00
13.86
50
2
40
FAYETTE
Distribution
Unattended
115.00
13.86
9
1
41
FERNWOOD
Distribution
Unattended
115.00
13.86
45
2
42
FLORA
Distribution
Unattended
115.00
14.49
28
1
43
FLORENCE
Distribution
Unattended
115.00
14.40
61
2
44
FLOWERS
Distribution
Unattended
115.00
13.80
40
2
45
FLOWOOD
Distribution
Unattended
115.00
14.49
67
2
46
FONDREN/JACKSON
Distribution
Unattended
115.00
14.49
78
3
47
FOREST HILL/JACKSON
Distribution
Unattended
115.00
13.86
56
2
48
GALLATIN STREET/JACKSON
Distribution
Unattended
115.00
13.86
56
2
49
GALLMAN
Distribution
Unattended
115.00
13.86
45
2
50
GEORGETOWN [MS]
Distribution
Unattended
115.00
13.80
12
1
51
GETWELL
Distribution
Unattended
230.00
13.80
80
2
52
GLEN ALLAN
Distribution
Unattended
115.00
13.86
5
1
53
GLOSTER
Distribution
Unattended
115.00
14.40
75
3
54
GRAND GULF DISTRIBUTION
Distribution
Unattended
115.00
14.49
20
1
55
GRANTS FERRY
Distribution
Unattended
230.00
13.86
71
2
56
GREENBROOK
Distribution
Unattended
115.00
14.40
95
3
57
GREENVILLE
Distribution
Unattended
115.00
13.86
56
2
58
GREENVILLE/EAST
Distribution
Unattended
115.00
13.86
42
2
59
GREENVILLE/INDUSTRIAL
Distribution
Unattended
115.00
13.86
50
2
60
GREENVILLE/MIDTOWN
Distribution
Unattended
115.00
13.86
45
2
61
GREENVILLE/NORTH
Distribution
Unattended
115.00
14.49
95
3
62
GREENVILLE/SOUTHEAST
Distribution
Unattended
115.00
13.86
28
1
63
GREENWOOD
Distribution
Unattended
115.00
13.86
45
2
64
GRENADA
Distribution
Unattended
115.00
13.86
78
3
65
GRENADA/SOUTH
Distribution
Unattended
115.00
13.86
50
2
66
HAINING ROAD
Distribution
Unattended
115.00
13.86
50
2
67
HAZLEHURST
Distribution
Unattended
115.00
13.86
50
2
68
HENDERSON ROAD
Distribution
Unattended
230.00
13.80
80
2
69
HERNANDO
Distribution
Unattended
115.00
13.86
83
2
70
HOLLANDALE
Distribution
Unattended
115.00
13.86
50
2
71
HORN LAKE
Distribution
Unattended
115.00
14.49
100
3
72
HOY ROAD
Distribution
Unattended
230.00
13.86
67
2
73
INDIANOLA 115 SUB
Distribution
Unattended
115.00
13.86
56
2
74
INVERNESS
Distribution
Unattended
115.00
13.86
32
2
75
JACKSON/EAST
Distribution
Unattended
115.00
13.86
101
3
76
JACKSON/NORTH
Distribution
Unattended
115.00
13.86
73
3
77
JACKSON/NORTHEAST
Distribution
Unattended
115.00
13.86
62
3
78
JACKSON/NORTHWEST
Distribution
Unattended
115.00
14.49
56
2
79
JACKSON/SOUTH
Distribution
Unattended
115.00
13.86
67
2
80
JACKSON/SOUTHWEST
Distribution
Unattended
115.00
13.86
67
3
81
JACKSON/TREATMENT PLANT
Distribution
Unattended
115.00
4.16
12
1
82
JACKSON/WATERWORKS
Distribution
Unattended
13.80
83
JACKSON/WEST
Distribution
Unattended
115.00
13.86
56
2
84
JOHNS MANVILLE
Distribution
Unattended
115.00
14.40
61
2
85
JONESTOWN
Distribution
Unattended
115.00
13.80
10
1
86
KINGSWOOD/JACKSON
Distribution
Unattended
115.00
13.86
56
2
87
KOSCIUSKO
Distribution
Unattended
115.00
14.40
68
2
88
LAKE CASTLE
Distribution
Unattended
230.00
14.49
67
2
89
LARSON ST/JACKSON
Distribution
Unattended
115.00
14.49
34
1
90
LELAND
Distribution
Unattended
115.00
14.49
46
2
91
LEXINGTON
Distribution
Unattended
115.00
13.86
35
2
92
LIBERTY
Distribution
Unattended
115.00
13.86
22
2
93
LIVINGSTON ROAD/JACKSON
Distribution
Unattended
115.00
14.40
62
2
94
LUCKNEY
Distribution
Unattended
230.00
13.86
67
2
95
LULA
Distribution
Unattended
115.00
13.86
20
1
96
MADISON
Distribution
Unattended
115.00
13.80
40
1
97
MAGEE
Distribution
Unattended
115.00
14.49
50
2
98
MARKS
Distribution
Unattended
115.00
13.86
45
2
99
MCCOMB
Distribution
Unattended
115.00
13.86
48
2
100
MCCOMB/WEST
Distribution
Unattended
115.00
13.86
50
2
101
MEADVILLE
Distribution
Unattended
115.00
13.86
20
1
102
MEDICAL CENTER/JACKSON
Distribution
Unattended
115.00
13.86
67
2
103
MENDENHALL
Distribution
Unattended
115.00
14.49
45
2
104
MIAMI STREET/JACKSON
Distribution
Unattended
115.00
14.40
33
1
105
MIDNIGHT
Distribution
Unattended
115.00
13.86
27
2
106
MILL STREET
Distribution
Unattended
115.00
13.80
80
2
107
MONUMENT STREET/JACKSON
Distribution
Unattended
115.00
14.49
76
3
108
MOORHEAD
Distribution
Unattended
115.00
14.49
48
2
109
MORTON
Distribution
Unattended
115.00
14.40
33
1
110
NATCHEZ
Distribution
Unattended
115.00
14.40
61
2
111
NATCHEZ/INDUSTRIAL PARK
Distribution
Unattended
115.00
14.49
56
2
112
NATCHEZ/SOUTH
Distribution
Unattended
115.00
13.86
50
2
113
NESBIT
Distribution
Unattended
115.00
13.86
45
2
114
NEW HEBRON
Distribution
Unattended
115.00
13.80
10
1
115
NORTHPARK
Distribution
Unattended
230.00
14.40
66
2
116
NORTHSIDE DRIVE/JACKSON
Distribution
Unattended
230.00
13.86
56
2
117
PELAHATCHIE
Distribution
Unattended
115.00
14.49
22
1
118
PICKENS
Distribution
Unattended
115.00
13.86
28
2
119
PLUM POINT
Distribution
Unattended
115.00
14.49
107
3
120
PORT GIBSON
Distribution
Unattended
115.00
13.86
68
2
121
RALEIGH
Distribution
Unattended
115.00
13.86
10
1
122
RANKIN
Distribution
Unattended
115.00
14.40
61
2
123
RANKIN INDTRL./JACKSON
Distribution
Unattended
115.00
13.86
56
2
124
RAYMOND
Distribution
Unattended
115.00
14.49
56
2
125
REX BROWN 115 SWYD
Distribution
Unattended
115.00
13.80
40
1
126
RIDGELAND
Distribution
Unattended
115.00
14.49
67
2
127
ROBINSON ROAD/JACKSON
Distribution
Unattended
230.00
13.86
56
2
128
ROBINSONVILLE
Distribution
Unattended
230.00
34.50
133
3
129
ROLLING FORK
Distribution
Unattended
115.00
13.86
35
2
130
ROSEDALE [MS]
Distribution
Unattended
115.00
13.86
35
2
131
ROXIE
Distribution
Unattended
115.00
14.40
10
1
132
RULEVILLE
Distribution
Unattended
115.00
13.86
42
2
133
SARDIS
Distribution
Unattended
115.00
13.80
40
2
134
SCHLATER
Distribution
Unattended
115.00
13.86
22
2
135
SENATOBIA
Distribution
Unattended
115.00
14.40
73
2
136
SHELBY
Distribution
Unattended
115.00
13.86
21
2
137
SILVER CREEK
Distribution
Unattended
115.00
13.86
50
2
138
SPENCER POTASH
Distribution
Unattended
115.00
13.86
22
1
139
SPRING RIDGE ROAD
Distribution
Unattended
115.00
13.86
34
1
140
STAR
Distribution
Unattended
115.00
13.86
22
2
141
STRINGTOWN
Distribution
Unattended
115.00
13.86
12
1
142
SUNNYBROOK
Distribution
Unattended
115.00
13.80
40
1
143
TERRY
Distribution
Unattended
115.00
13.80
52
2
144
TINNIN ROAD
Distribution
Unattended
230.00
13.80
40
1
145
TUNICA
Distribution
Unattended
115.00
13.86
22
1
146
TWINKLETOWN
Distribution
Unattended
230.00
14.40
33
1
147
TYLERTOWN
Distribution
Unattended
115.00
13.86
38
3
148
UTICA
Distribution
Unattended
115.00
13.86
30
2
149
VICKSBURG
Distribution
Unattended
115.00
13.86
42
2
150
VICKSBURG/EAST
Distribution
Unattended
115.00
13.86
42
2
151
VICKSBURG/NORTH
Distribution
Unattended
115.00
13.86
70
3
152
VICKSBURG/OPENWOOD
Distribution
Unattended
115.00
13.86
28
1
153
VICKSBURG/SOUTH
Distribution
Unattended
115.00
13.86
42
2
154
VICKSBURG/SOUTHEAST
Distribution
Unattended
115.00
13.86
28
1
155
VICKSBURG/WEST
Distribution
Unattended
115.00
14.40
53
2
156
WALLS
Distribution
Unattended
115.00
13.86
9
1
157
WEBB
Distribution
Unattended
115.00
13.86
17
2
158
WESSON
Distribution
Unattended
115.00
14.49
28
1
159
WHITFIELD
Distribution
Unattended
115.00
13.86
22
1
160
WINONA
Distribution
Unattended
115.00
13.86
45
2
161
WOODVILLE [MS]
Distribution
Unattended
115.00
13.86
12
1
162
WYNNDALE
Distribution
Unattended
115.00
13.80
80
2
163
YANDELL RD
Distribution
Unattended
230.00
13.86
100
3
164
YAZOO CITY SS
Distribution
Unattended
115.00
13.86
12
1
165
ATTALA
Transmission
Unattended
230.00
120.00
(c)
13.80
392
1
166
ATTALA PLANT
Transmission
Unattended
500.00
167
BATESVILLE [MS]
Transmission
Unattended
230.00
120.00
13.86
392
1
168
BAXTER WILSON SES SWYD
Transmission
Unattended
500.00
115.00
1176
2
169
BEECH GROVE SS
Transmission
Unattended
115.00
170
BOWLING GREEN SS
Transmission
Unattended
115.00
171
CHOCTAW
Transmission
Unattended
500.00
172
DELTA SWYD
Transmission
Unattended
115.00
173
ELLIOTT SS
Transmission
Unattended
115.00
174
FRANKLIN EHV
Transmission
Unattended
500.00
115.00
13.80
1120
2
175
FREEPORT
Transmission
Unattended
500.00
230.00
13.86
975
1
176
GERALD ANDRUS SES SWYD
Transmission
Unattended
230.00
120.00
13.86
392
1
177
GETWELL
Transmission
Unattended
230.00
115.00
13.80
392
1
178
GRAND GULF TRANSMISSION
Transmission
Unattended
500.00
179
GRENADA/SOUTH
Transmission
Unattended
230.00
115.00
500
1
180
HARPER
Transmission
Unattended
115.00
181
HORN LAKE
Transmission
Unattended
230.00
161.00
13.80
1027
3
182
INDIANOLA 230/115 SUB
Transmission
Unattended
230.00
120.00
392
1
183
JACKSON/SOUTH
Transmission
Unattended
230.00
120.00
13.86
392
1
184
JONESTOWN SS
Transmission
Unattended
115.00
185
LAKEOVER EHV
Transmission
Unattended
500.00
230.00
1215
2
186
MCADAMS EHV
Transmission
Unattended
500.00
230.00
1500
2
187
MINTER CITY SS
Transmission
Unattended
115.00
188
MOON LAKE SS
Transmission
Unattended
230.00
189
NATCHEZ SWYD
Transmission
Unattended
115.00
190
PICKENS
Transmission
Unattended
230.00
120.00
13.86
392
1
191
RANKIN
Transmission
Unattended
230.00
120.00
13.86
392
1
192
RAY BRASWELL EHV
Transmission
Unattended
500.00
230.00
13.86
2073
4
193
REX BROWN 230 SWYD
Transmission
Unattended
230.00
120.00
13.86
392
1
194
SHELBY SS
Transmission
Unattended
115.00
195
TILLATOBA
Transmission
Unattended
230.00
120.00
13.86
392
1
196
TUNICA 230/115 SUB
Transmission
Unattended
230.00
120.00
392
1
197
VICKSBURG/EAST SS
Transmission
Unattended
115.00
198
WOLF CREEK
Transmission
Unattended
500.00
199
YAZOO CITY MUNICIPAL SS
Transmission
Unattended
115.00
200
TotalDistributionSubstationMember
164
201
TotalGenerationSubstationMember
0
202
TotalTransmissionSubstationMember
35
203
Total
199


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
FOOTNOTE DATA

(a) Concept: PrimaryVoltageLevel
Voltage in columns (c), (d), and (e) is reported in KV and not MVa.
(b) Concept: SecondaryVoltageLevel
Voltage in columns (c), (d), and (e) is reported in KV and not MVa.
(c) Concept: TertiaryVoltageLevel
Voltage in columns (c), (d), and (e) is reported in KV and not MVa.

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
TRANSACTIONS WITH ASSOCIATED (AFFILIATED) COMPANIES
  1. Report below the information called for concerning all non-power goods or services received from or provided to associated (affiliated) companies.
  2. The reporting threshold for reporting purposes is $250,000. The threshold applies to the annual amount billed to the respondent or billed to an associated/affiliated company for non-power goods and services. The good or service must be specific in nature. Respondents should not attempt to include or aggregate amounts in a nonspecific category such as "general".
  3. Where amounts billed to or received from the associated (affiliated) company are based on an allocation process, explain in a footnote.
Line No.
Description of the Good or Service
(a)
Name of Associated/Affiliated Company
(b)
Account(s) Charged or Credited
(c)
Amount Charged or Credited
(d)
1
Non-power Goods or Services Provided by Affiliated
2
(a)
See footnote for schedule details
3
(b)
See footnote for allocation method details
19
20
Non-power Goods or Services Provided for Affiliated
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2022
Year/Period of Report

End of:
2021
/
Q4
FOOTNOTE DATA

(a) Concept: DescriptionOfNonPowerGoodOrService
Entergy service companies, including Entergy Operations, and Entergy Services, provide recurring, ongoing services to Entergy affiliates. Service company transactions are reported in the schedule below by type of category, where the amount charged or credited for each category is equal to or greater than the $250,000 threshold. All other Non-service company affiliate transactions reported in this schedule, if any, are reported by individual detailed transaction.

Line No. Description of the Non-Power Good or Service Name of Associated/Affiliated Company Account Charged or Credited Amount Charged or Credited
(a) (b) (c) (d)
1 Non-power Goods or Services Provided by Affiliate
2 Administration Entergy Services 107000, 108230, 163000, 174101, 184001, 228100, 253053, 408110, 421000, 426100, 426500, 431000, 454000, 500000, 506000, 511000, 514000, 517000, 529000, 560000, 563000, 566000, 569000, 580000, 583000, 588000, 591000, 886000, 903001, 920000, 921000, 923000, 926000, 930100, 930200, 931000, 935000 2,066,979 
3 Corporate - Legal Services Entergy Services 107000, 174101, 408110, 426100, 426400, 426500, 500000, 506000, 514000, 517000, 524000, 880000, 909000, 910000, 920000, 921000, 923000, 926000, 928000, 930100, 930200, 931000, 935000 2,851,313 
4 Corporate - Office of the Chief Executive Officer Entergy Services 107000, 174101, 184001, 408110, 426500, 557000, 903002, 920000, 921000, 923000, 925000, 930200, 931000, 935000 300,836 
5 Corporate - Public Relations Entergy Services 107000, 174101, 174200, 408110, 426100, 426400, 426500, 514000, 524000, 588000, 908000, 909000, 920000, 921000, 923000, 926000, 930100, 930200, 931000 2,590,591 
6 Corporate Support - General Entergy Services 107000, 108230, 121WIP, 163000, 174101, 174200, 181CPD, 183000, 183KSL, 184001, 1840FS, 184EST, 228100, 4031AM, 408110, 408155, 408158, 426100, 426400, 426500, 430000, 500000, 506000, 510000, 512000, 514000, 517000, 520000, 524000, 528000, 532000, 535000, 546000, 549000, 551000, 556000, 557000, 560000, 561200, 561300, 561500, 563000, 566000, 568000, 569000, 570000, 573000, 580000, 583000, 584000, 586000, 588000, 590000, 592000, 593000, 596000, 598000, 901000, 902000, 903001, 903002, 904000, 905000, 907000, 908000, 909000, 910000, 916000, 920000, 921000, 923000, 924000, 925000, 926000, 928000, 930200, 931000, 935000 20,036,461 
7 Customer Service Entergy Services 107000, 228100, 408110, 560000, 568000, 903001, 907000, 910000, 913000, 916000, 920000, 921000, 926000, 930100, 931000 262,367 
8 Customer Service Support Entergy Services 107000, 174101, 408110, 901000, 902000, 903001, 903002, 905000, 907000, 910000, 913000, 920000, 926000, 928000, 931000 7,016,791 
9 Distribution Entergy Services 107000, 163000, 174101, 174200, 184001, 1840FS, 184EST, 408110, 560000, 566000, 580000, 581000, 584000, 586000, 587000, 588000, 589000, 590000, 591000, 592000, 597000, 598000, 902000, 903001, 903002, 904000, 920000, 921000, 923000, 926000, 930200 7,377,629 
10 Finance and Accounting Entergy Services 107000, 163000, 174101, 181CPD, 183KSL, 184001, 1840FS, 184EST, 228100, 253053, 408110, 426100, 426300, 426400, 431000, 500000, 506000, 507000, 514000, 517000, 546000, 560000, 580000, 901000, 903002, 905000, 907000, 910000, 920000, 921000, 923000, 924000, 925000, 926000, 928000, 930200, 931000, 935000 7,537,701 
11 Fossil Operations Entergy Services 107000, 174101, 228100, 408110, 500000, 506000, 507000, 510000, 512000, 513000, 514000, 535000, 546000, 549000, 551000, 553000, 556000, 560000, 920000, 921000, 923000, 926000 6,493,603 
12 Human Resources Entergy Services 107000, 174101, 408110, 426100, 426300, 426500, 514000, 517000, 524000, 580000, 913000, 920000, 921000, 923000, 926000, 926NS1, 928000, 930200, 931000, 935000 3,605,075 
13 Information Technology Entergy Services 107000, 174101, 174200, 184001, 1840FS, 1840NC, 228100, 408110, 426400, 454000, 500000, 506000, 514000, 517000, 524000, 532000, 539000, 546000, 549000, 560000, 561200, 561500, 566000, 567000, 568000, 569200, 573000, 580000, 588000, 589000, 598000, 901000, 903001, 903002, 920000, 921000, 923000, 926000, 928000, 930200, 931000, 935000 29,036,755 
14 Operations and Performance Entergy Services 107000, 174101, 174200, 184001, 228100, 408110, 426100, 426500, 500000, 506000, 514000, 524000, 546000, 549000, 560000, 566000, 580000, 588000, 903001, 920000, 921000, 923000, 926000, 930100, 930200, 931000, 935000 1,434,445 
15 Supply Chain Entergy Services 107000, 163000, 174101, 184001, 228100, 408110, 426400, 500000, 506000, 514000, 517000, 524000, 546000, 560000, 566000, 580000, 588000, 920000, 921000, 923000, 926000, 930200 2,861,822 
16 System Benefits Entergy Services 107000, 108230, 163000, 174101, 174200, 181CPD, 183KSL, 184001, 1840FS, 184EST, 228100, 408110, 426100, 426400, 426500, 568000, 904000, 920000, 921000, 923000, 926000, 926NS1, 930200 22,767,290 
17 System Planning Entergy Services 107000, 174101, 408110, 500000, 506000, 507000, 511000, 514000, 549000, 556000, 557000, 561200, 5612BA, 566000, 580000, 904000, 920000, 921000, 923000, 926000, 928000, 930200 2,907,712 
18 Tax And Interest Expense Entergy Services 408122, 408123, 408142, 408152, 408156, 408165, 409112, 409114, 409148, 409149, 410101, 410120, 411110, 411120, 411430, 419000, 419011, 430000, 431000, 431003 2,471,107 
19 Transmission Entergy Services 107000, 174101, 174200, 184001, 184EST, 228100, 408110, 556000, 560000, 561200, 561300, 561500, 561600, 566000, 567000, 568000, 569000, 569100, 573000, 580000, 588000, 590000, 592000, 593000, 903001, 904000, 913000, 920000, 921000, 926000, 928000 16,191,552 
20 Utility Management and Support Services Entergy Services 107000, 174101, 184001, 184EST, 408110, 426100, 426400, 426500, 506000, 580000, 581000, 588000, 590000, 593000, 870000, 901000, 903002, 907000, 909000, 910000, 913000, 916000, 920000, 921000, 923000, 926000, 928000, 930100, 930200, 931000, 935000 20,273,131 
21 Utility Support - Distribution Entergy Services 107000, 163000, 174101, 184001, 1840FS, 408110, 426100, 426400, 426500, 546000, 560000, 580000, 586000, 588000, 596000, 598000, 902000, 903001, 903002, 907000, 908000, 913000, 920000, 921000, 923000, 925000, 926000, 930200 4,761,612 
22 Utility Support - Operations Entergy Services 107000, 174101, 408110, 903001, 909000, 911000, 913000, 916000, 920000, 921000, 923000, 926000, 930200 2,522,160 
23 Wholesale Ops Corporate Support Entergy Services 107000, 183KSL, 408110, 426100, 514000, 549000, 568000, 590000, 913000, 920000, 921000, 923000, 926000, 928000, 930100, 930200, 931000 1,852,360 
24 Distribution Support - Truck stock lighting and materials installation. Entergy Arkansas 107000 852,013 
25 Storm Distribution Support - Repairs, Coordination and Management of Storm Restoration. Entergy Arkansas 174101 1,599,663 
26 Distribution Support - Installation of meters, wires, and lighting. Including maintenance and safety. Entergy Arkansas 597000, 593000, 587000, 107000, 595000 2,173,276 
27 Inventory Transfers of Materials and Supplies. Entergy Arkansas 154PAS 2,230,530 
28 Inventory Transfers of Materials and Supplies. Entergy Louisiana 154PAS, 163000 2,378,900 
29 Non-power Goods or Services Provided for Affiliate
30 Inventory Transfers of Materials and Supplies. Entergy Arkansas 154PAS 335,788 
31 Inventory Transfers of Materials and Supplies. Entergy Louisiana 154PAS, 163000 2,061,111 
32 Storm Distribution Support - Repairs, Coordination and Management of Storm Restoration. Entergy Louisiana 174101 4,835,608 
33 Distribution Support - Installation of meters, wires, and lighting. Including maintenance and safety. Entergy Louisiana 107000 1,535,943 
34 Distribution Support - Truck stock lighting and materials installation. Entergy Louisiana 107000 418,765 
(b) Concept: DescriptionOfNonPowerGoodOrService
Listed below are the allocation factors used to allocate costs to the affiliate.
Note: Where no allocation factor is provided for the non-power goods or services listed on Schedule 429, the costs associated with those goods and services were directly charged and not allocated.

Description of the Non-Power Good or Service Cost Allocator(s)
Entergy Services
Administration APPSUPAL, ASSTSALL, ASSTSREG, CUSEOPCO, CUSTEGOP, DSTLNALL, EMPLOYAL, GENLEDAL, ITSPENDA, LBRBILAL, LBRCORPT, LBRLEGAL, LVLSVCAL, SQFTALLC, TRALINOP, TRANSPND, TRASUBOP, TRSBLNOP
Corporate - Legal Services APTRNALL, ASSTSALL, ASSTSREG, CAPAOPCO, CAPXCOPC, CUSEGAMI, CUSEOPCO, CUSTCALL, CUSTEGOP, EMPLOFOS, EMPLOREG, EMPLOYAL, EMPLTRAN, GENLDREG, GENLEDAL, ITSPENDA, LBRBILAL, LBRCOMUN, LBRCORPT, LBRFDPOL, LBRFINAN, LBRINFOR, LBRLEGAL, LBRUTOPN, LVLSVCAL, OWNISFI, PCNUMALL, PKLOADAL, PRCHKALL, RECDMGNT, SCDSPALL, SCPSPALL, SQFTALLC, TRALINOP, TRANSPND, TRSBLNOP
Corporate - Public Relations ASSTSALL, CAPAOPCO, CUSEOPCO, CUSTEGOP, EMPLOREG, EMPLOYAL, LBRCOMUN, LBRCORPT, LBRFDPOL, LBRLEGAL, MACCTALL, PKLOADAL, TRSBLNOP
Corporate Support - General APPSUPAL, APTRNALL, ARTRNALL, ASSTSALL, ASSTSREG, BNKACCTA, CAPAOPCO, CAPXCOPC, COMCLAIM, CUSEGAMI, CUSEGXTX, CUSEOPCO, CUSTCALL, CUSTEGOP, CUSTEXTX, DSTLNALL, EMPLFRAN, EMPLOCSS, EMPLOFOS, EMPLOREG, EMPLOYAL, EMPLPRES, EMPLTRAN, EMPLUTOP, EMPXRTNC, GENLDREG, GENLEDAL, GPASSTAL, GPASSTDS, GPASSTTN, INSPREAL, ITSPENDA, LBRBILAL, LBRCOMUN, LBRFDPOL, LBRFINAN, LBRINFOR, LBRLEGAL, LBRSUPCN, LBRUTOPN, LVLSVCAL, MACCTALL, NETPPEAL, OWNISFI, PCNUMALL, PCNUMXNR, PKLDXEAI, PKLOADAL, PRCHKALL, RADIOALL, RECDMGNT, SCDSPALL, SCFSPALL, SCMATRAN, SCMATXNU, SCPSPALL, SCPSPXNC, SCTDSPAL, SCTSPALL, SQFTALLC, TELPHALL, TRALINOP, TRANSPND, TRASUBOP, TRSBLNOP, UNPOWSAL, VEHCLFOS, VEHCLUSG
Customer Service Support ASSTSALL, CUSEGAMI, CUSEGXTX, CUSEOPCO, CUSTCALL, CUSTEGOP, CUSTEXTX, CUSTOEAM, EMPLOYAL, EMPLUTOP, LBRCORPT, MACCTALL
Distribution CUSEGAMI, CUSEOPCO, CUSTEGOP, EMPLFRAN, EMPLOYAL, GPASSTAL, GPASSTDS, GPASSTTN, LBRBILAL, LBRCORPT, LBRFDPOL, PCNUMALL, SCPSPALL, TRALINOP, TRANSPND, TRASUBOP, TRSBLNOP, VEHCLFOS, VEHCLUSG
Finance and Accounting APPSUPAL, APTRNALL, ARTRNALL, ASSTSALL, ASSTSREG, BNKACCTA, CAPAOPCO, CAPXCOPC, CUSEGAMI, CUSEOPCO, CUSTEGOP, EMPLOREG, EMPLOYAL, EMPLPRES, GENLDREG, GENLEDAL, GPASSTAL, GPASSTDS, INSPREAL, ITSPENDA, LBRBILAL, LBRCOMUN, LBRFDPOL, LBRFINAN, LBRINFOR, LBRLEGAL, LBRSUPCN, LBRUTOPN, LVLSVCAL, NETPPEAL,
OWNISFI, PCNUMALL, PKLOADAL, PRCHKALL, SCDSPALL, SCMATRAN, SCPSPALL, SQFTALLC, TRANSPND, TRSBLNOP, UNPOWSAL, VEHCLFOS, VEHCLUSG
Fossil Operations ASSTSALL, CAPAOPCO, CUSEOPCO, CUSTEGOP, EMPLOYAL, EMPXRTNC, LBRCORPT, LBRSUPCN, PKLOADAL, SCDSPALL, SCFSPALL, TELPHALL, VEHCLFOS
Human Resources APPSUPAL, ASSTSALL, ASSTSREG, CAPAOPCO, CUSEGAMI, CUSEOPCO, CUSTEGOP, EMPLFRAN, EMPLOCSS, EMPLOFOS, EMPLOREG, EMPLOYAL, EMPLPRES, EMPLTRAN, EMPLUTOP, GENLEDAL, ITSPENDA, LBRBILAL, LBRCORPT, LBRFINAN, LBRLEGAL, LBRUTOPN, LVLSVCAL, NETPPEAL, PKLOADAL, PRCHKALL, SCDSPALL, SQFTALLC, TRSBLNOP
Information Technology APPSMVSX, APPSUNIX, APPSUPAL, APPSWINT, APTRNALL, ARTRNALL, ASSTSALL, ASSTSREG, CAPAOPCO, CUSEGAMI, CUSEGXTX, CUSEOPCO, CUSTCALL, CUSTEGOP, DSTLNALL, EMPLOYAL, GENLEDAL, GPASSTAL, GPASSTDS, GPASSTTN, ITSPENDA, LBRBILAL, LBRCORPT, LBRINFOR, LVLSVCAL, PCNUMALL, PCNUMXNR, PKLOADAL, PRCHKALL, RADIOALL, RECDMGNT, SCDSPALL, SCMATRAN, SCMATXNU, SCPSPALL, SCPSPXNC, SCTDSPAL, SQFTALLC, TELPHALL, TRALINOP, TRANSPND, TRASUBOP, TRSBLNOP
Operations and Performance APPSUPAL, ASSTSALL, CAPAOPCO, CUSEOPCO, CUSTEGOP, EMPLFRAN, EMPLOREG, EMPLOYAL, EMPLTRAN, EMPXRTNC, LBRBILAL, LBRLEGAL, PKLOADAL, SCPSPALL, TRASUBOP, TRSBLNOP
Supply Chain APTRNALL, ASSTSALL, ASSTSREG, CAPAOPCO, CUSEGAMI, CUSEOPCO, CUSTEGOP, EMPLOYAL, GPASSTAL, GPASSTDS, LBRCORPT, LBRSUPCN, LBRUTOPN, LVLSVCAL, PCNUMALL, SCDSPALL, SCFSPALL, SCMATRAN, SCMATXNU, SCPSPALL, SCPSPXNC, SCTDSPAL, SCTSPALL, TRANSPND
System Benefits APPSUPAL, APTRNALL, ARTRNALL, ASSTSALL, ASSTSREG, BNKACCTA, CAPAOPCO, CAPXCOPC, COMCLAIM, CUSEGAMI, CUSEGXTX, CUSEOPCO, CUSTCALL, CUSTEGOP, CUSTEXTX, DSTLNALL, EMPLFRAN, EMPLOCSS, EMPLOFOS, EMPLOREG, EMPLOYAL, EMPLPRES, EMPLTRAN, EMPLUTOP, EMPXRTNC, GENLDREG, GENLEDAL, GPASSTAL, GPASSTDS, GPASSTTN, INSPREAL, ITSPENDA, LBRBILAL, LBRCOMUN, LBRFDPOL, LBRFINAN, LBRINFOR, LBRLEGAL, LBRSUPCN, LBRUTOPN, LVLSVCAL, MACCTALL, NETPPEAL, OWNISFI, PCNUMALL, PCNUMXNR, PKLDXEAI, PKLOADAL, PRCHKALL, RADIOALL, RECDMGNT, SCDSPALL, SCFSPALL, SCMATRAN, SCMATXNU, SCPSPALL, SCPSPXNC, SCTDSPAL, SCTSPALL, SQFTALLC, TELPHALL, TRALINOP, TRANSPND, TRASUBOP, TRSBLNOP, UNPOWSAL, VEHCLFOS, VEHCLUSG
System Planning ASSTSALL, ASSTSREG, CAPAOPCO, CAPXCOPC, CUSEOPCO, CUSTEGOP, EMPLOYAL, LBRBILAL, PKLOADAL, TRANSPND
Tax And Interest Expense LVLSVCAL
Transmission ASSTSALL, CAPAOPCO, CUSEGAMI, CUSEOPCO, CUSTEGOP, EMPLOYAL, EMPLTRAN, EMPLUTOP, GENLEDAL, GPASSTAL, GPASSTTN, LBRCORPT, PCNUMALL, PCNUMXNR, PKLOADAL, SCDSPALL, SCTDSPAL, SCTSPALL, TELPHALL, TRALINOP, TRANSPND, TRASUBOP, TRSBLNOP
Utility Management and Support Services APPSUPAL, ARTRNALL, ASSTSALL, ASSTSREG, CAPAOPCO, CUSEGAMI, CUSEOPCO, CUSTCALL, CUSTEGOP, EMPLOYAL, EMPLUTOP, GENLDREG, GENLEDAL, GPASSTAL, GPASSTDS, GPASSTTN, ITSPENDA, LBRBILAL, LBRCORPT, LBRFDPOL, LBRINFOR, LBRLEGAL, LBRUTOPN, LVLSVCAL, MACCTALL, PCNUMALL, PKLDXEAI, PKLOADAL, PRCHKALL, SCDSPALL, SCPSPALL, SCTDSPAL, TRANSPND, TRASUBOP
Utility Support - Distribution ASSTSALL, CAPAOPCO, COMCLAIM, CUSEGAMI, CUSEOPCO, CUSTCALL, CUSTEGOP, EMPLOYAL, GPASSTAL, GPASSTDS, LBRCORPT, LBRLEGAL, LBRSUPCN, LVLSVCAL, MACCTALL, PCNUMXNR, PKLOADAL, SCDSPALL, SCFSPALL, SCLDTMLS, SCPSPALL, SCPSPXNC, SCTSPALL, TRANSPND, VEHCLFOS, VEHCLUSG
Utility Support - Operations ASSTSREG, CAPAOPCO, CUSEGAMI, CUSEOPCO, CUSTEGOP, EMPLOYAL, GPASSTAL, GPASSTDS, MACCTALL, PCNUMALL, SCDSPALL, SCPSPALL, TELPHALL, TRASUBOP
Wholesale Ops Corporate Support ASSTSALL, ASSTSREG, CAPAOPCO, CUSEOPCO, CUSTEGOP, EMPLOYAL, ITSPENDA, LBRUTOPN, LVLSVCAL, PCNUMALL, PKLOADAL, TRALINOP, TRANSPND

Cost Allocator Descriptions

Cost Allocator Cost Allocator Title Cost Allocator Description
Entergy Services
APPSMVSX Server and Mainframe Usage - MVS Based on mainframe usage
APPSUNIX Server and Mainframe Usage - UNIX Based on UNIX server usage
APPSUPAL Server and Mainframe Usage - Composite Based on a weighted composite of UNIX and NT servers and mainframe usage
APPSWINT Server and Mainframe Usage - NTS Based on WINTEL server usage
APTRNALL Accounts Payable Transactions Based on a twelve-month number of accounts payable transactions processed
ARTRNALL Accounts Receivable Invoices Based on a twelve-month number of accounts receivable transactions processed
ASSTSALL Total Assets Based on total assets at period end
ASSTSREG Total Assets - Regulated business units Based on total assets at period end for all regulated Business Units
BNKACCTA Bank Accounts Based on number of bank accounts at period end
CAPAOPCO System Capacity Based on the power level, in kilowatts, that could be achieved if all non-nuclear generating units were operating at maximum capability simultaneously
CAPXCOPC System Capacity - Excluding Coal and Nuclear Based on the power level, in kilowatts, that could be achieved if all non-coal and non-nuclear generating units were operating at maximum capability simultaneously
COMCLAIM Workers' Compensation Claims Based on number of open workers' compensation claims
CUSEGAMI Customers - AMI Only Based on a twelve-month average number of electric-only, gas-only, and dual (electric and gas) customers derived from the number of gas-only customers provided by Gas Operations. This method should only be used to allocate Advanced Metering Infrastructure
CUSEGXTX Electric and Gas Customers - Excluding Entergy Texas Based on a twelve-month average number of electric and gas residential, commercial, industrial, government, municipal, and general business customers, excluding ETI
CUSEOPCO Electric Customers Based on a twelve-month average number of electric residential, commercial, industrial, government, and municipal customers
CUSTCALL Customer Call Centers Based on a twenty-four month average of customer calls
CUSTEGOP Electric and Gas Customers Based on a twelve-month average number of electric and gas residential, commercial, industrial, government, and municipal general business customers
CUSTEXTX Electric Customers - Excluding ETI Based on a twelve-month average number of electric residential, commercial, industrial, government, and municipal customers for EAI, ELA, EMI, and ENOI
CUSTOEAM Electric Customers - EAI and EMI Based on a twelve-month average number of electric residential, commercial, industrial, government, and municipal customers for EAI and EMI
DSTLNALL Distribution Line Miles Based on the number of miles of distribution lines
EMPLFRAN Employees - Franchise Operations Based on the number of full-time and part-time employees within Franchise Operations
EMPLOCSS Employees - Customer Support Services Based on the number of full-time and part-time employees within Customer Support Service
EMPLOFOS Employees - Fossil Plant Operations Based on the number of full-time and part-time employees within Fossil Plant Operations
EMPLOREG Full-Time and Part-Time Employees - EAI, ELA, EMI, ENOI, SERI, ETI, and ESI Based on the number of full-time and part-time employees at period end for EAI, ELA, EMI, ENOI, SERI, ETI, and ESI
EMPLOYAL Full-Time and Part-Time Employees Based on the number of full-time and part-time employees at period end
EMPLPRES Employees - State President Based on the number of full-time and part-time employees within State President Organizations
EMPLTRAN Employees - Transmission Based on the number of full-time and part-time employees within Transmission
EMPLUTOP Employees - Utility Operations Based on the number of full-time and part-time employees within Utility Operations
EMPXRTNC Regulated Employees Based on the number of full-time and part-time employees at period end for EAI, ELA, EMI, ENOI, ETI, and ESI (excluding Nuclear)
GENLDREG General Ledger Transactions - Regulated Companies Based on general ledger transactions for regulated companies
GENLEDAL General Ledger Transactions Based on general ledger transactions
GPASSTAL Gross Utility Plant Assets - Operating Companies Based on the gross value of utility plant assets at period end for all Entergy Operating Company
GPASSTDS Gross Electric Transmission Utility Plant Assets - Operating Companies Based on the gross value of electric distribution utility plant assets at period end for all Entergy Operating Companies
GPASSTTN Gross Electric Transmission Utility Plant Assets - Operating Companies Based on the gross value of electric transmission utility plant assets at period end for all Entergy Operating Companies
INSPREAL Insurance Premiums Based on non-nuclear insurance premiums
ITSPENDA Information Technology Total Spending Based on Information Technology twelve-month total spending
LBRBILAL ESI Labor Costs Billed Based on total labor dollars billed to each Client Company by ESI
LBRCOMUN ESI Labor Billed - Communications Based on total labor dollars billed to each company by ESI for the Communications function
LBRCORPT ESI Labor Billed - Corporate Based on total labor dollars billed to each company by ESI for the Corporate function
LBRFDPOL ESI Labor Billed - Federal Policy, Regulatory and Governmental Affairs Based on total labor dollars billed to each company by Entergy Services for the Federal Policy, Regulatory and Governmental Affairs function
LBRFINAN ESI Labor Billed - Finance Based on total labor dollars billed to each company by ESI for the Finance function
LBRINFOR ESI Labor Billed - IT Based on total labor dollars billed to each company by ESI for the IT function
LBRLEGAL ESI Labor Billed - Legal Based on total labor dollars billed to each company by ESI for the Legal function
LBRSUPCN ESI Labor Billed - Supply Chain Based on total labor dollars billed to each company by ESI for the Supply Chain function
LBRUTOPN ESI Labor Billed - Utility Operations Based on total labor dollars billed to each company by ESI for the Utility Operations function
LVLSVCAL ESI Service Level Based on ESI total billings to each Client Company
MACCTALL Managed Accounts Based on number of retail managed accounts
NETPPEAL Net Property, Plant, and Equipment Based on the net book value of all companies with property, plant and equipment, excluding natural gas and nuclear fuel
OWNISFI Percentage Ownership - SFI Based on the percentage ownership of SFI
PCNUMALL Number of PC's Based on the number of PC's within each Business Unit
PCNUMXNR Number of PC's - Excluding Non-Regulated Business Units Based on the number of PC's within each regulated Business Unit at EAI, ELA, EMI, ENOI, SERI, ETI, and ESI
PKLDXEAI Peak Load - Excluding EAI Based on the ratio of each Client Company’s load to the peak load at time of all companies peak load excluding EAI. The calculation of Peak Load Ratio is performed using a twelve-month rolling average of the coincident peaks.
PKLOADAL Peak Load Ratio Based on the ratio of each Client Company’s load to the peak load at time of all companies peak load. The calculation of Peak Load Ratio is performed using a twelve-month rolling average of the coincident peaks.
PRCHKALL Payroll Checks Issued Based on the number of payroll checks issued for each Business Unit
RADIOALL Radio Usage Based on usage of Entergy's 2-way radio system
RECDMGNT Records Management Based on the number of full-time and part time employees at period end, excluding the Nuclear function using records management services
SCDSPALL Supply Chain Spending - Distribution Based on Supply Chain Procurement Total Spending for the Distribution Function
SCFSPALL Supply Chain Spending - Fossil Based on Supply Chain Procurement Total Spending for the Fossil Function
SCLDTMLS Supply Chain - Labor Dollars Based on Supply Chain Labor Dollars for the Transformer, Meter, and Light Shops
SCMATRAN Supply Chain Transactions in Passport Based on the number of Supply Chain materials transactions for each Business Unit in Passport
SCMATXNU Supply Chain Transactions in Passport - Excluding Nuclear Based on the number of Supply Chain materials transactions for each Business Unit in Passport, excluding the Nuclear function
SCPSPALL Supply Chain Total Spending Based on Supply Chain's Procurement Total Spending
SCPSPXNC Supply Chain Spending - Excluding Nuclear Based on Supply Chain Procurement Total Spending, excluding Nuclear for twelve months
SCTDSPAL Supply Chain Spending - Distribution and Transmission Based on Supply Chain's Procurement Total Spending for Distribution and Transmission functions
SCTSPALL Supply Chain Spending - Transmission Based on Supply Chain's Procurement Total Spending for Transmission
SQFTALLC Square Footage - All Companies Based on square footage for all Business Units
TELPHALL Number of Telephones Based on the number of telephones within each Business Unit
TRALINOP Transmission Line Miles Based on the number of miles of transmission lines, weighted for design voltage (Voltage < 400kv = 1; Voltage >400kv =2)
TRANSPND Transmission Budgeted Capital Expenditures Based on Transmission Budgeted Capital Expenditures
TRASUBOP Transmission Substations Based on the number of high voltage substations weighted for Voltage (Voltage < 500kv = 1; Voltage >= 500kv = 2)
TRSBLNOP Transmission Line Miles/Substation Based on two components: Transmission Line Miles (30% weighting) and the Number of High Voltage Substations (70% weighting)
UNPOWSAL Unit Power Sales Agreement Based on allocation factors in connection with Entergy's Unit Power Sales Agreement. This allocates capacity, energy, and related costs from GG 1
VEHCLFOS Number of Vehicles - Fossil Based on the number of vehicles owned or leased by each Business Unit for the Fossil function only
VEHCLUSG Number of Vehicles - Excluding Fossil and Nuclear Based on the number of vehicles owned or leased by each Business Unit that participates in the usage based transportation allocation, excluding Fossil and Nuclear
XBRL Instance File
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